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Home My WebLink About175-005Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/04/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL LRU 1A (PTD 175-005) PERFORATING RECORD 03/27/2021 Please include current contact information if different from above. PTD: 1750050 E-Set: 35087 Received by the AOGCC 05/04/2021 05/04/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,480 feet 2,730 feet true vertical 9,480 feet N/A feet 2098, 3883, Effective Depth measured 2,730 feet 4676, 5470 feet true vertical 2,730 feet feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8; 2-3/8" 6.4#/L-80; 4.6#/N-80 5760; 4691' MD 5760; 4691' TVD Tubing (size, grade, measured and true vertical depth)1-1/4" heater 2.3#/L-80 1956' MD/TVD Baker SSV; 279' MD/TVD Packers and SSSV (type, measured and true vertical depth)(4) Otis Pkrs 2098', 3833', 4676', 5470' MD/TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 0 Water-Bbl MD 48' 363' 1,368' 0 Oil-Bbl measured true vertical Packer 9-5/8" 48' 8,147'8,147' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 ewis River Field / Undefined Gas PoolN/A measured TVD Tubing Pressure 7100 Lewis River 1 N/A ADL0058801 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 175-005 50-283-20047-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-110 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 363' 1,368' 8,147' Conductor Surface Intermediate Production 4,750psi Casing Structural 30" 20" 13-3/8" Length 48' 2,730psi Collapse 1,130psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 6,870psi 363' 1,368' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:06 am, Apr 09, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.09 09:58:30 -08'00' Taylor Wellman (2143) DSR-4/12/21 RBDMS HEW 4/9/2021 L SFD 4/15/2021BJM 5/7/21 Rig Start Date End Date E-Line 3/26/21 3/27/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name LRU-01 50-283-20047-00-00 175-005 03/27/2021 - Saturday Moved to location. Spot equipment. Rig up, RIH with 1-11/16" GGR, 1-11/16"WB, 1-11/16" Spangs, 2.23LIB, to depth 2,340'. Correlate to 1,988' POOH. Lay down PCE for evening. Send correlation log to town. Morning Meeting, JSA PTW, Start up equipment. Rig up, standby for depth determination correlation to determine whether to RIH. Correlation tag Depth 2,341.1'. Rig up strip gun 14'. RIH with 1-11/16" x 14' strip gun to depth of 2,320' - 2,334' (CCL -20.2 set to 2,299.8 shot depth). Correlated. Shot 1-11/16" x 14' strip gun to depth of 2,320' -2,334' (CCL - 20.2 set to 2,299.8 shot depth). All shot fired POOH. OOH. Rig Down. 03/26/2021- Friday Daily Operations: Shot 1-11/16" x 14' strip gun to depth of 2,320' -2,334' Updated by DMA 04-07-21 SCHEMATIC Lewis River 1A PTD 175-005 API# 50-083-20047-00-00 Completed 09-08-06 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 30” - LP Surf 48’ Driven ––– 20” 94 H-40 Butt 19.124 Surf 363’ 26” 456sx 13-3/8” 54.5 K-55 12.615 Surf 943’ 17-1/2” 1031sx 61 12.515 943’ 1,368’ 9-5/8” 47 P-110 8.681 7,907’ 8,147’ 12-1/4” 400sx CBL Ratty 4500’ to 5568’ S-95 6,985’ 7,907’ N-80 4,502’ 6,985’ DV Collar 4,500’ 4,502’ 1150sx (Cmt to Surf) CBL Ratty 0 to 2580’ N-80 8.681 Surf 4,500’ TUBING DETAIL 2-7/8” 6.4 N-80 Butt SC 2.441 Surf 4,691’ 2-3/8” 4.6 N-80 Butt SC 1.995 4,691’ 5,760’ 1-1/4” 2.3 L-80 CS Hydril 1.380 Surf 1,956’ JEWELRY DETAIL NO. Depth Length ID OD Item 14.50’ McEvoy Dual Tubing Hanger, 2-7/8” x 2-7/8” SLRT 11” 5M 1. 297’ 2.5’ 2.313 3.25 3.85 Otis “XXO” SSSV Landing Nipple (P/N 11 XXO 23100) 2. 2,065’ 3.37’ 2.313 3.75 Otis “XA” Sldg Slve 3. 2,098’ 12.0’ 2.44 4.44 Otis Straight Slot Seal Assy w/ 11’ of Seals 13.81’ 3.88 8.30 Otis “VST” Production Pkr w/ 7.46’ SBE 3A. 2,730’ Halliburton 2-7/8” CIBP 4. 3,883’ 12.0’ 2.44 4.12 Otis Straight Slot Seal Assy w/ 11’ of Seals 13.87’ 3.88 8.30 Otis “VST” Production Pkr w/ 7.52’ SBE 5. 3,930’ 3.35’ 2.313 3.75 Otis “XA” Sldg Slve 6. 3,934’ 4,382’ 20’,18’,28’, 34’,19’,19’ 2.441 3.50 Carbide Blast Rings; 3934’–3965’, 3994’–4025’, 4091’–4122’, 4187’–4247’4263’–4294’, 4352’–4382’ 7. 4,646’ 3.34’ 2.313 3.75 Otis “XA” Sldg Slve 8. 4,676’ 10.09’ 2.44 4.12 Otis Straight Slot Seal Assy w/ 9’ of Seals 14.48’ 3.88 8.30 Otis “VST” Production Pkr w/ 8.11’ SBE 9. 4,691’ 0.70’ 1.94 3.52 Crossover, 2-7/8” BTC x 2-3/8” BTC 10. 4,721’ 1.32’ 1.875 2.90 Otis “X” Profile Nipple 11. 5,470’ 10.19’ 2.44 4.12 Otis Straight Slot Seal Assy w/ 9’ of Seals 14.47’ 3.88 8.30 Otis “VST” Production Pkr w/ 8.09’ SBE 12. 5,516’ 3.34’ 1.875 3.03 HES “XA” Sldg Slve 13. 5,729’ 1.32’ 1.875 2.90 HES “X” Profile Nipple 14. 5,760’ 0.76’ 1.94 6.05 WLEG PERFORATION DETAIL Zone Top Btm Amt SPF Comments Sterling A 2,320' 2,334' 14' 6 Open on 3/27/21 Sterling 4 / Beluga 25-6 2,679' 2,687' 8' 6 Open on 9/8/06 Upper Beluga 2,718' 2,722' 4' 6 Open 9/16/09 Upper Beluga 2,754' 2,762' 8' 6 Isolated Upper Beluga 2,790' 2,792' 2' 2 Sqz'd, Isolated Upper Beluga 2,802' 2,819' 17' 6 Isolated Upper Beluga 2,822' 2,828' 6' 6 Isolated Upper Beluga 2,829' 2,832' 3' 2 Sqz'd, Isolated Upper Beluga 3,084' 3,091' 7' 6 Isolated Upper Beluga 3,092' 3,094' 2' 4 Sqz'd, DST Upper Beluga 3,647' 3,651' 4' 4 Sqz'd, DST Upper Beluga 3,715' 3,722' 7' 6 Isolated Upper Beluga 3,723' 3,725' 2' 4 Sqz'd, DST Upper Beluga 3,800' 3,828' 28' 6 Isolated Upper Beluga 3,850' 3,856' 6' 6 Isolated Middle Beluga 3,948' 3,958' 10' 8 Isolated Middle Beluga 4,008' 4,016' 8' 4 Isolated Middle Beluga 4,096' 4,116' 20' 8 Isolated Middle Beluga 4,202' 4,210' 8' 8 Isolated Middle Beluga 4,227' 4,233' 6' 4 Isolated Middle Beluga 4,278' 4,287' 9' 8 Isolated Middle Beluga 4,360' 4,369' 9' 8 Isolated Lower Beluga 4,730' 4,738' 8' 8 Sqz'd, Production Lower Beluga 4,984' 4,994' 10' 8 Sqz'd, Production Lower Beluga 5,014' 5,036' 22' 8 Sqz'd, Production Upper Tyonek 5,528' 5,553' 25' 4,8,4 Isolated Upper Tyonek 5,576' 5,600' 24' 8 Isolated Upper Tyonek 5,668' 5,688' 20' 4,8,4 Isolated Upper Tyonek 5,707' 5,715' 8' 12 Isolated Upper Tyonek 5,736' 5,764' 28' 4,8,4,8,4 Isolated 6,097' 6,102' 5' 4 DST Isolated 7,725' 7,730' 5' 4 DST Isolated p Sterling A 2,320'2,334'14'6 Open on 3/27/21 Zone Top Btm Amt SPF Comments CBL Ratty 0 to 2580’ CBL Ratty 4500’ to 5568’ 7\SHRI5HTXHVW$EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG3HUIRUDWH2WKHU6WLPXODWH3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 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Operations Abandon Repair Well Plug Perforations Stimulate ~~~~>~ (~~; ; f~;~, ~Ofttftll53s" Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ [~tIG19r'Waiver ^ Time Extension ^ ~ .. .. -> Change Approved Program ^ Operat. Shutdown ^ Perforate-.[-+}-~ Re-e ter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory ^ 175-005 3. Address: PO Box 196247, Anchorage, AK 99519. Stratigraphic Service .API Number: 50-283-20047-00 Property Designation (Lease Number): Well Name and Number. ADL0058801 [Lewis River Facility] Lewis River 1 10. Field/Pool(s): Lewis River Field /Undefined Gas Pool 11. Present Well Condition Summary: Total Depth measured ~ 9,480 feet Plugs (measured) 2,730 feet true vertical 9,480 feet Junk (measured) N/A feet 2,098', 3,883', Effective Depth measured 2,730 feet Packer (measured) 4,676', 5,470' feet 2,098', 3,883', true vertical 2,730 feet (true vertical) 4,676', 5,470' feet Casing Length Size MD TVD Burst Collapse Structural 48' 30" 48' 48' Conductor 363' 20" 363' 363' Surface 1,368' 13-3/8" 1,368' 1,368' 2,730 psi 1,130 psi Intermediate Production 8,147' 9-5/8" 8,147' 8,147' 6,870 psi 4,750 psi Liner flfl Perforation depth: Measured depth: 2,679-2,687', 2,718'-2,722' True Vertical depth: 2,679-2,687', 2,718'-2,722' 2-7/8" / 2-3/8" / 6.4#N-80 / 4.6#N-80 5,760' / 4,691' / 5,760' / 4,691' / Tubing (size, grade, measured and true vertical depth): 1-1/4" (heater) / 2.3#L-80 1,956' 1,956' 2,098', 3,883', 4,676', 5,470'MD / 297' MD / Packers and SSSV (type, measured and true vertical depth): (4) Otis Packers 2,oss', 3,as3~, a,s7s', s,a7o~rvD Baker SSV 297' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 540 psi Subsequent to operation: 0 0 0 0 psi 500 psi 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Q Service ^ Daity Report of Well Operations X .Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-390 Contact Chris Kanyer 263-7831 Printed Nam Timothy C. Brandenburg Title Drilling Manager Signature ~ ~ ~ Phone 276-7600 Date 1/11/10 Form 10-404 Revised 7/2009 RBDMS JAN 121010 ~- Submit Original Only ~Ch Chevron -Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (Tt) LRU 1A LEWIS RIVER 1 ADL0058801 5028320047 QA9398 118.00 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Perforating -Post Production Well 9/4/2009 9/17/2009 Services Primary Wellbore Affected Wellbore UWI Well Permit Number LRU 1A 502832004700 1750050 - ,~ `~,, O erati ,~s ---- - -- - 12IT/2009 00:00 - 12/8/2009 00:00 _ Operations Summary RU slickline. Pressure test lubricator to 250psi low/2500psi high. Run 2.25" GR to 2717' RKB (slm) Bail sand to 2734' RKB (slm). SDFN. - ----- 12/8/2009 OOc00 -.12/9/2009.00:00 _ _ Operations Summary RU slickline. Pressure test lubricator to 250psi low/2500psi high. Bail sand to 2742' RKB (wlm). Run selective shifting tool to sliding sleeve at 2076' RKB (slm) correlate to Schlumberger completion record dated 16-Sep-09 . slickline measurement 6 ft deep actual correlated fill depth of 2736' RKB correlated. SDFN. 1219/2009 00:00 -12/1012009 00:00 _ Operations Summary RU slickline and pressure test lubricator 250psi low/2500psi high. RIH and tag fill with 2.27" GR at 2742' RKB (slm), Rig up E-Line and pressure test lubricator 250psi low/2500psi high. R_IH Halliburton Macro Bridge Plug to 2725.5' RKB correlated to completion record. POOH w/ plug and decide to bail more fill. Rig back Eline. ---- f 12/10/2009 00200 -12I11/2009'OOt00 _ ___ ____ ____ _ Operations Summary RU slickline and pressure test lubricator 250psi low/2500psi high. Bail fill to 2742' RKB (slm), RD slickline. RU Eline and pressure test lubricator 250psi low/2500psi high. RIH and Set Halliburton 2 7/8" MACCO bridge plug at 2730' RKB correlated to completion record dated 16 Sept 2009. RD Eline, turned well over to production. ~~ ~ uNOCa~76 Lewis River Well lA Completed 9/8/06 RKB = 16.5' CASING AND TiJRING DETAIL S17,E WT GRADF. CONN ID TOP BTM. Hole Size CMT 30" - LP Surf 48' Driven - 20" 94 H-40 Butt 19.124 Surf 363' 26" 456sx " 54.5 12.615 Surf 943' 1/2" 17 1031 13-3/8 61 K-55 12.515 943' 1,368' - sx P-110 7,907' 8,147' 5-95 8.681 6,985' 7,907' 400sx 4500' to 5568' CBL R t 9-5/8" 47 N-80 4,502' 6,985' 12-1/4" a ty DV Collar 4,500' 4,502' l I50sx (Cmt to sur0 N-80 8.681 Surf 4,500' CBL Ratty o to zsso' Tubin 2-7/8" 6.4 N-80 Butt SC 2.441 Surf 4,691' 2-3/8" 4.6 N-80 Butt SC 1.995 4,691' 5,760' 1-1/4" 2.3 L-80 CS H dril 1.380 Surf 1,956' .IEWELRY DETAIL NO. De th Len th ID OD Item 14.50' McEvo Dual Tubin Han er, 2 7/8" x 2-7/8" SLRT 11" SM 1. 297' 2.5' 2.313 3.25 3.85 Otis "XXO" SSSV Landing Nipple P/N 11 XXO 23100 2. 2,065' 3.37' 2.313 3.75 Otis "XA" Sld Slve ' 12.0' 2.44 4.44 Otis Straight Slot Seal Assy w/ 11' of Seals 3. 2,098 13.81' 3.88 8.30 Otis "VST" Production Pkr w/ 7.46' SBE 3A. 2,730' Halliburton 2-7/8" CIBP ' 12'0' 2.44 4.12 Otis Straight Slot Seal Assy w/ 11' of Seals 4. 3,883 13.87' 3.88 8.30 Otis "VST" Production Pkr w/ 7.52' SBE 5. 3,930' 3.35' 2.313 3.75 Otis "XA" Sldg Slve 6' 3,934' q 3g2° 20',18',2s', 34',19',19' 2.441 3.50 Carbide Blast Rings; 3934'-3965', 3994'025', 4091'--0122', 4187'~247'4263'~294' 4352'382' 7. 4,646' 3.34' 2.313 3.75 Otis "XA" Sldg Slve ' 10.09' 2.44 4.12 Otis Straight Slot Seal Assy w/9' of Seals 8. 4,676 14.48' 3.88 8.30 Otis "VST" Production Pkr w/ 8.1 ]' SBE 9. 4,691' 0.70' 1.94 3.52 Crossover, 2-7/8" BTC x 2-3/8" BTC 10. 4,721' 1.32' L875 2.90 Otis "X" Profile Nipple ' 10.19' 2.44 4.12 Otis Straight Slo[ Seal Assy w/9' of Seals 11. 5,470 14.47' 3.88 8.30 Otis "VST" Production Pkr w/ 8.09' SBE 12. 5,516' 3.34' 1.875 3.03 HES "XA" Sldg Slve 13. 5,729' 1.32' 1.875 2.90 HES "X" Profile Nipple 14. 5,760' 0.76' 1.94 6.05 WLEG PERFORATION INTERVAL Inte rval Accun. Zone Top Btm Amt spf Comments Be-t 25( 2679' 2,687' 8' 6 OPEN on9/8/06 U er Be-t 2,718' 2,722' 4' 6 en 9/16/2009 U erBeW 2754' 2762' 8' 6 Isolated U er Be 790' 2 7 2' S z' Is at U erBeYt 2,802' 2$19' 17 6 Isolated U erBeL 822 2828' 6' 6 Isolated U erBe6 2,829 2$32' 3' 2 S zd, Isolated erBe6 3084' 3091' 7' 6 Isolated U erBe~ 3,092' 3094' 2' 4 S zd, DST U erBekt 3,647 3651' 4' 4 S zd, DST U er BeYt 3 71 S 3 722' 7' 6 Isolated U er BeW 3723' 3,725' 2' 4 S z'd, DST U erBei~ 3800' 3,828' 28 6 Isolated er so a MiddleBel 3,948 3,958' 10' 8 Isolated Mi;lAeBel 4,008 4Q 16' 8' 4 Isolated M e B 4,096 4,116' 2d 8 plated M' dleBeluga 4,202 410' 8' 8 Isolated Middle Be uBt 4,227 433' 6' 4 l~ ated e e tt~ so a e uga so a wer e uga qz on wer a uga qz m wer a uga qz m er ate . so a UpperTymek 5,576 5600' 24' 8 Isoated UpperTyate 5,668 5 88' 2d 4,8,4 Isoat U er T ate 5, 5 7 5 1 I so at Peer yme so a a 0 LRU lA Schematic Current 12-30-09 .doc DRAWN BY: BCA REVISED: 12/30/09 Max Hole Angle = Straight hole u i j g S t SEAN PARNELL, GOVERNOR v g ALASKA OIL AND GA,S 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Timothy C. Brandenburg Drilling Manager Unocal P.O. Box 196427 th e 1\10V t ZOOS Anchorage, AK 99519 S 1 q Re: Lewis River Field, Undefined Gas Pool, Lewis River 1 Sundry Number: 309 -390 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4 :30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court -hearing has been requested. Sincerely, tit o,. o 'an Comrrn 'oner DATED this day of November, 2009 Encl. ft �l RECEIVED �4. C �O ®t STATE OF ALASKA it/ f a f to °9 4" ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 1 7 2009 I APPLICATION FOR SUNDRY APPROVALS Cons. Commission 20 AAC 25.280 Alaska Oil Gas 1. Type of Request: Abandon I: Suspend Operational shutdown El Perforate Re -enter SuspenAMi a ±L Alter casing Repair well Plug Perforations 0 Stimulate Other Specify: Change approved program Pull Tubing Perforate New Pool Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Ei Exploratory 175 -005 3. Address: Stratigraphic Service 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 283 20047 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes No 0 Lewis River 1 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0058801 [Lewis River Facility] Lewis River Field Undefined Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9,480 9,480 2,765 2,765 2,775 (cement) 2,728 (fill) Casing Length Size MD V ND Burst Collapse Structural 48' 30" 48' 48' Conductor 363' 20" 363' 363' Surface 1,368' 13 -3/8" 1,368' 1,368' 2730 psi 1130 psi Intermediate Production 8,147' 9 -5/8" 8,147' 8,147' 6870 psi 4750 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -7/8" 2 -3/8" 1 -1/4 "(heater) 6.4#N -80 4.6 #N -80 2.3 #L -80 5,760' 4,691' 1,956' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): (4) Otis VST packers Baker SSSV 2,098'.,3,883' 4,676' 5,470' 297' 12. Attachments: Description Summary of Proposal El 11: Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development 0 Service 14. Estimated Date for -/11/22/09 15. Well Status after proposed work: Commencing Operations: Oil Gas 0 WDSPL Plugged 16. Verbal Approval: Date: WINJ GINJ WAG Abandoned Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature c t Phone Date 11/16/09 s COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 309-3 Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Subsequent Form Required: 10 4 0 APPROVED BY Approved by: MISSIONER THE COMMISSION Date: -19 R t1 V161 I 0!( i7.6`x" -1/9- ;'1. L #ANAL Form 10 -403 Revised 7/2009 Submit in Duplicate Chevron Lewis River Unit 44101 Well LRU 1A %.11' 11/16/09 OBJECTIVE: Isolate lower Beluga sands due to water production. PROCEDURE SUMMARY: 1. RU slickline and pressure test lubricator to 250 psi low /2500 psi high. 2. RIH w/ GR and tag fill at 2,728' RKB. 3. Attempt to bail fill to 2,754' RKB. 4. Rig down slickline. 5. RU Eline and pressure test lubricator to 250 psi low /2500 psi high. 6. Set CIBP at 2,740' RKB. 7. Rig down E -Line and turn well over to production. LRU lA REVISED BY: CVK 11 -16 -09 Lewis River lidettlifflatill Well lA UNOCAL 76 Completed 9/8/06 CASING AND TUBING DETAIL RKB 16.5' SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 30" LP Surf 48' Driven J m 1 20" 94 H-40 Butt 19.124 Surf 363' 26" 456sx e s L 54.5 12.615 Surf 943' 13 -3/8" 61 K -55 12.515 943' 1,368' 17 -1/2" 1031sx I P -110 7,907' 8,147' '441 S -95 8.681 6,985' 7,907' 400sx '1* I 9 -5/8" 47 N -80 4,502' 6,985' 12 -1/4" CBI. Ratty 4500' to 5568' DV Collar 4,500' 4,502' 1150sx (Cmt to surf) N -80 1 1 8.681 Surf 4,500' CBt. Ratty o to 2580' Tubing -v.�. 2 -7/8" 6.4 N -80 Butt SC 2.441 Surf 4,691' 2 -3/8" 4.6 N -80 Butt SC 1.995 4,691' 5,760' 1 -1/4" 2.3 L -80 CS Hydril 1.380 Surf 1,956' 'et JEWELRY DETAIL t•/ NO. Depth Length ID OD Item to 14.50' McEvoy Dual Tubing Hanger, 2-7/8" x 2 -7/8" SLRT 11" 5M 2 1. 297' 2.5' 2.313 3.25 Otis "XXO" SSSV Landing Nipple I 3 3.85 (P/N 11 XXO 23100) TOC 2118' 0 2. 2,065' 3.37' 2.313 3.75 Otis "XA" Sldg Sive 12.0' 2.44 4.44 Otis Straight Slot Seal Assy w/ 11' of Seals B d ••ga 25-6 3. 2,098 13.81' 3.88 8.30 Otis "VST" Production Pkr w/ 7.46' SBE 2619'2687' 12.0' 2.44 4.12 Otis Straight Slot Seal Assy w/ 11' of Seals 1 4. 3,883' 13.87' 3.88 8.30 Otis "VST" Production Pkr w/ 7.52' SBE C mt Ret 2775' -0. 5. 3,930' 3.35' 2.313 3.75 Otis "XA" Sldg Sive 6 3,934' 20',18',28', 2.441 3.50 Carbide Blast Rings, 3934'- 3965', 3994' -4025', 4,382' 34'.19'.19' 4091'- 4122', 4187' -4247'4263' -4294', 4352' -4382' i 7. 4,646' 3.34' 2.313 3.75 Otis "XA" Sldg Sive i 10.09' 2.44 4.12 Otis Straight Slot Seal Assy w /9' of Seals 8. 4,676' 14.48' 3.88 8.30 Otis "VST" Production Pkr w/ 8.11' SBE 9. 4,691' 0.70' 1.94 3.52 Crossover, 2 -7/8" BTC x 2 -3/8" BTC 10. 4,721' 1.32' 1.875 2.90 Otis "X" Profile Nipple 10.19' 2.44 4.12 Otis Straight Slot Seal Assy w /9' of Seals 11 5,470' 4 14.47' 3.88 8.30 Otis "VST" Production Pkr w/ 8.09' SBE CIBP @3910' 12. 5,516' 3.34' 1.875 3.03 HES "XA" Sldg Sive 13. 5,729' 1.32' 1.875 2.90 HES "X" Profile Nipple 14. 5,760' 0.76' 1.94 6.05 WLEG DV@ 4500'' 7 PERFORATION INTERVAL -s Interval Acorn. r./ 8 Zone Top Btm Amt spf Comments Beluga 256 2,679 2087' 8' 6 OPEN on 9/8/06 9 Up.er Bat ,t 2,718 2722' 4' 6 en 9/16/2009 U,.erBelt,. 2754' 2762' 8' 6 •.en9'16/2009 Upper Be {n 2' Sqi• Is at:. U,.erBelt.. 802' 17 6 Isolated UpperBeltgp 2,822' 2,828' 6' 6 Isolated Upper Beluga 2,829 2,832' 3' 2 Sgz'd, Isolated i t. rBeV� 3084' 3091' 7' 6 1 I..` 1 1 Upper Beluga 3,092' 3 094' 2' 4 Sgz'd, DST M 1 41 a U,. er Bell.. 3,647 3 .51' 4' 4 S z'd, DST i Upper Beidgi 3,715' 3722' 7' 6 Isolated Upper Beluga 3,723' 3,725' 2' 4 Sgz'd, DST .,,...3jli�. y i }1u3i4.:}v tl{; {t +ti't1t1Fi'i}t;s:,.,,;1ij:r,. U,. er Belt. 3800' 3:28' 28 6 Isolated ,111: l 1` t`;, pp t Itn :1. 1 p a 1 Meidle Beluyp 3,948' 3 ,958' 10' 8 Isolated ts(t 1 1 t .('I1 M iddle Behan 4,008' 4016' 8' 4 Isolated Junk@ 5855 Middle Behan 4,096 4,116' 20' 8 Isolated CBP@ 5900' Middle Belubn 4,202 4210' 8' 8 Iplated Middle Beluyg 4,227 4233' 6' 4 Isolated CBP @7650' EgPiC MMUMIIIIMIMMsa •II e1 .1 C. 93 a:. Cmt 8000'-8176' 10.1110 musiim b'gair•'ilrrt[Dl• yit •we' 1 e ugl •:'f' IIIIM=.111MIII Cmt 9044' -9144' 0 ewer tetiLu ,1 ,1 .qz Im Cmt 9380' 9480'" Upper Iyatek 5,528' 5,553' 25' 4,8,4 plated t4. Upper Tyatek 5,576 5,600' 24' 8 plated TD =9480' Upper Tyatek 5,668 5,688' 20' 4,8,4 plated Max Hole Angle Straight hole MU'n31 MUM= MAME. tipper yate 93 a 1 /.125 1 s' 1 4 IDS 1A Schematic Current 11 -9 -09 .doc DRAWN BY: CVK REVISED: 11/9/09 wietriimati Lewis River PROPOSED Well 1A UNOCAL() Completed 9/8/06 CASING AND TUBING DETAIL RKB 16.5' SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 30" LP Surf 48' Driven 1 20" 94 H -40 Butt 19.124 Surf 363' 26" 456sx L 13 -3/8" 54.5 K -55 1 S urf 943' 17 -1/2" I031sx 61 1 2.515 943' 1,368' 0 s P -110 7,907' 8,147' .1 ;1 S -95 8 .6 81 6,985' 7,907' CBL Re tty45500' to 5568' 9 -5/8" 47 N -80 4,502' 6,985' 12 -1/4" DV Collar 4,500' 4,502' 1150sx (Cmt to surf) i N -80 1 1 8.681 Surf 4,500' CBL Ratty 0 to 2580' Tubing 2 -7/8" 6.4 N -80 Butt SC 2.441 Surf 4,691' 2 -3/8" 4.6 N -80 Butt SC 1.995 4,691' 5,760' 1 -1/4" 2.3 L -80 CS Hydril 1.380 Surf 1,956' JEWELRY DETAIL NO. Death Length ID OD Item 14.50' McEvoy Dual Tubing Hanger, 2 -7/8" x 2 -7/8" SLRT 11" 5M `B 3.25 Otis "XXO" SSSV Landing Nipple 1. 297' 2.5' 2.313 3 3.85 (P/N 11 XXO 23100) 2. 2,065' 3.37' 2.313 3.75 Otis "XA" Sldg Sive roc *2118' 1 12.0' 2.44 4.44 Otis Straight Slot Seal Assy w/ 11' of Seals M 25 -6 3. 2098' 13.81' 3.88 8.30 Otis "VST" Production Pkr w/ 7.46' SBE CIBP I 1 9'2687 3A. 2,740'( 7.5' Halliburton 2 -7/8" CIBP Proposed i 4. 3,883' 12.0' 2.44 4.12 Otis Straight Slot Seal Assy w/ 11' of Seals Cmt Ret 2775' +tue 13.87' 3.88 8.30 Otis "VST" Production Pin w/ 7.52' SBE 5. 3,930' 3.35' 2.313 3.75 Otis "XA" Sldg Sive 6 3,934' 20',18',28', 2,441 3.50 Carbide Blast Rings 3934'- 3965', 3994'-4025', 4,382' 34',19',19' 4091' -4122', 4187' -4247'4263'- 4294', 4352' -4382' 1 7. 4,646' 3.34' 2.313 3.75 Otis "XA" Sldg Sive 8. 4,676' 10.09' 2.44 4.12 Otis Straight Slot Seal Assy w /9' of Seals 14.48' 3.88 8.30 Otis "VST" Production Pkr w/ 8.11' SBE i t 9. 4,691' 0.70' 1.94 3.52 Crossover, 2 -7/8" BTC x 2 -3/8" BTC 10. 4,721' 1.32' 1.875 2.90 Otis "X" Profile Nipple CI, 4 10.19' 2.44 4.12 Otis Straight Slot Seal Assy w /9' of Seals C IBP 3910' 11. 5,470' 14.47' 3.88 8.30 Otis "VST" Production Pkr w/ 8.09' SBE 12. 5,516' 3.34' 1.875 3.03 HES "XA" Sldg Slve 13. 5,729' 1.32' 1.875 2.90 HES "X" Profile Nipple 14. 5,760' 0.76' 1.94 6.05 WLEG DV 4500' PERFORATION INTERVAL MR I nterval Ac con. F i t 8 Zone Top Btm Amt spf Comments Beltga25'6 2,679 2¢87' 8' 6 OPENon9 /8/06 TE E: #lah?I£ }i{ 9 U 1, er Belt 2,715 2 722' 4' 6 t„ 1.2009 Upper Be 2,754' 2762' 8' 6 Open 9/16/2C09 UpperBeupp 2790 792' 2' 2 Sqzd Isdated UyerBeki 802' 2:19' IT 6 Isolated UI.a Bell l 2822 2:28' 6' Olsolated U,. erBelt. 2829 3' 2 S. z. Isdazed MEM Mr= 3 084'11 ®0 1 74 ■:,it 11 Upper Beluga 3,092' 3094' 2' 4 Sgz'c DST w U,.erBelu- 3647 3.51' 4' 4 S. id, DST 1 LlpperBeltga 3,715 3,722' 7' 6 Isolated Upper Belt Ka 3,723' 3,725' 2' 4 Sqz'd, DST' U1.erBelu 3,800 3$28' 28 6 Isolated pper t. iga 1 so a Middle Beluga 3,948 3958' 10 8 Isolated IL, Middle Below 4,008' 4016' 8' 4 Isolated Junk@ 5855' Middle Beluga 4,096 4,116' 20 8 Isolated CBP@ 5900' Middle Belugl 4,207 4,210' 8' 8 Isolated Mildle Beluyn 4,227' 4,233' 6' 4 Isolated CIBP@ 7650' Middle Belts 4,2/8 4 ,287' 9' 8 Isolated _G. .de raga r soa... Cmt 8000' 8176' IcIts, Iowa Beluga 4, /317 17 W 8 5 Sgi4 Production InZajannilirdialkilillMMIMMAIMIIIIMIGURWArd Cmt 9044' -9144' `i!.ili' ,L wer le ugu ,1 ,I qz tm Upper lyatek 5,528' 5,553' 25' 4,8,4 solated Cmt 9380'- 9480' ps•+I Upper Tycnek 5,576' 5,600' 24' 8 solated T D 9480' Upper Tyatek 5,668 5,6 20 4,8,4 solated Max Hole Angle Straight hole u,.erT cnek 5,707 5,715' 8' 12 solated tipper yate so .1 I`. 1 o: /,/25 760' 5' 4 DS1bolded LRU 1A Proposed Schematic 11 -16 -09 .doc DRAWN BY: CVK REVISED: 11/16/09 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I~G/t- ~~1~3~~a4 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-e ter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory ~ 175-005 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service . API Number: 50-283-20047-00 Property Designation (Lease Number): . Well Name and Number: ADL0058801 [Lewis River Faciliry~ L wis River 1 0. Field/Pool(s): lewis River Field / Undefined Gas Pool 11. Present Well Condition Summary: Total Depth measured .~; 9,480 feet Plugs (measured) 2,775 (cement) feet true vertical 9,480 feet Junk (measured) 2,763 (fill) feet 2,098', 3,883', Effective Depth measured 2,763 feet Packer (measured) 4,676', 5,470' feet 2,098', 3,883', true vertical 2,763 feet (true vertical) 4,676', 5,470' feet Casing Length ~Size MD ND Burst Collapse Structural 48' 30" 48' 48' Conductor 363' 20" 363' 363' Surface 1,368' 13-3/8" ~30 psi 1,368' $~ a a 1,130 psi Intermediate ~ ~~' ~ G V V Production 8,147' 9-5/8" 8,147' 8,147' 6,870 psi 4,750 psi Liner , ~U~f ~ ~ ~QQg "t"114 - 2~`L~ Perforation depth: Measured depth:5,0U9:-fi;998'~^ ~eska Oil ~ Gas ~ons. ~i~fE11111~SiQ~ Anchnr~g~ True Vertical depth: , - / 2-7/8" / 2-3/8" / 6.4#N-80 / 4.6#N-80 5,760' / 4,691' / 5,760' / 4,691' / Tubing (size, grade, measured and true vertical depth): 1-1/4" (heater) / 2.3#L-80 1,956' 1,956' ,098' ,883', 4,676', 5,470'MD / 297' MD / Packers and SSSV (type, measured and true vertical depth): (4) Otis Packers ~o , s,ass~, a,s7s~, s,a7o~rvo gaker SSV 29~' ND 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~~~ ~~ ~ ~ ~ ~On~ ~~ N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 500 psi Subsequent to operation: 0 . 0 0 0 psi 380 psi 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Q Service ^ Daily Report of Well Operations X . Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-277 Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg ` Title Drilling Manager _~ ~ ~ ~ ~ ~ Signature y ~_ , Phone 276-7600 Date 11/9/09 .~ ~ f~80~lIS NUY 1 3 zuUy Form 10-404 Revised 7/2009 ~~~ " `. Submit Original Only ~Chevron Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) LRU 1A LEWIS RIVER 1 ADL0058801 5028320047 QA9398 118.00 >.. .. ~,., ~k~~~ r.;; ~ > ~ ~ ~ ~~~,~~~`~a =~•;~; ~'r ~., .n ~ ~ ~ ,.~ .w ~ ,. ~ w~ ~ ~~ Primary Job Type Job Category Objective Actual Start Date Actual End Date Perforating - Post Production Well 9/4/2009 9/17/2009 Services Primary Wellbore Affected Wellbore UWI Well Permit Number LRU 1A 502832004700 1750050 > ri 3 Dai "b ratfo~. ~ ~ ~ ~,~ ~ ` 9/4/2009 OOsOQ - 9/5t2009 00:Od Operations Summary RU slickline. Pressure test lubricator to 250psi low/2500psi high. RIH, bail sand from 2,765' to 2769' RKB SLM. Fluid Level found at 2677' RKB. RD slickline. 9/16t2009 OO:b6 ~ 9/171~b~1~ 00:00 Operations Summary RU Schlumberger wireline and pressure tested lubricator 250psi low/ 2500psi high. Tagged fill at 2763' RKB. Fluid level at 2672'. Perf Upper Beluga j sands w/ 2.5" PJ Omega, 6spf, 60 deg phased guns from 2754'- 2762' and 2718' to 2722'. RD Eline. Turned well over to production. -~ uNOCa~~b Lewis River Well lA Completed 9/8/06 RKB = 16.5' CASING AND TUBING DETAIL SI'LE WT GRADE CONN ID TOP BTM. Hole Size C~1T 30" - LP Surf 48' Driven - 20" 94 H-40 Butt 19.124 Surf 363' 26" 456sx " 54.5 12.615 Surf 943' / " 1031 13-3/8 61 K-55 12.515 943' 1,368' 17-1 2 sx P-I10 7,90T 8,147' S-95 8.681 6,985' 7,90T 400sx CBL R 4500' t 5568' 9-5/8" 47 N-80 4,502' 6,985' 12-1/4" atry o DV Collar 4,500' 4,502' 1150sx (Cmt to Sur~ N-80 8.681 Surf 4,500' Ce~ xatry o to zsso' Tubin 2-7/8" 6.4 N-80 Butt SC 2.441 Surf 4,691' 2-3/8" 4.6 N-80 Butt SC 1.995 4,691' S,760' I-1/4" 23 L-80 CS H dril L380 Surf 1,956' JEWELRY DETAIL NO. De th Len th ID OD Item 14.50' McEvo Dual Tubin Han er, 2 7/8" x 2-7/8" SLRT 1 I" SM l. 29T 2.S 2.313 325 3.85 Otis "XXO" SSSV Landing Nipple P/N 11 XXO 23100 2. 2 065' 33T 2313 3.75 Otis "XA" Sld Slve ' ~z'0' 2.44 4.44 Otis Straight Slot Seal Assy w/ I 1' of Seals 3. 2,098 13.81' 3.88 830 Otis "VST" Production Pkr w/ 7.46' SBE ' 12.0' 2.44 4.12 Otis Straight Slot Seal Assy w/ 11' of Seals 4. 3,883 13.87' 3.88 8.30 Otis "VST" Productian Pkr w/ 7.52' SBE 5. 3,930' 335' 2313 3.75 Otis "XA" Sldg Slve 6' 3,934' q 3gZ° 20',~8',28', 34',19',19' Z.441 3.50 Cazbide Blast RingS 3934'-3965', 3994'~025', 4091'--0122', 4187'-424T4263'~294' 4352'-4382' 7. 4,646' 334' 2313 3.75 Otis "XA" Sldg Slve ' 10.09' 2.44 4.12 Otis Straight Slot Seal Assy w/9' of Seals 8. 4,676 ~ 4.48' 3.88 830 Otis "VST" Production Pkr w/ 8.11' SBE 9. 4,691' OJO' I.94 3.52 Gossover, 2-7/8" BTC x 2-3/S" BTC 10. 4,721' 1.32' 1.875 2.90 Otis "X" Profile Nipple ' ~0.19' 2.44 4.12 Otis Straight Sbt Seal Assy w/9' of Seals 11. 5,470 14.47' 3.88 830 Otis "VST" Production Pkr w/ 8.09' SBE 12. 5,516' 334' 1.875 3.03 HES "XA" Sldg Slve 13. 5,729' I 3Y I.875 2.90 HES "X" Profile Nipple 14. 5,760' 0.76' 1.94 6.05 WLEG PERFORATION INTERVAL Interval Accun. _ Znne Top Btm Amt spf Commenls BeW 256 2,679 2687' 8' 6 OPENon9/8/06 U erBeW z718 2,7?2' 4' 6 ~9/I(~/?(p9 U erBe6 2754' 2762' 8' b at9/16/2009 U er I3e i ,7 i Is at U erBeli~ 2802' 2~19' 1T 6 l~lated _ U er BeW 2,ffi2 2~828' 6' 6 I~lated U erBeW 2829' 2~32' 3' 2 S id Isdated er 3 084' 3 09 ' 7' 6 1 lat U erBeW 3,092' 3094' 2' 4 S zd DST U erBeli 3,647 3b51' 4' 4 S id, DSC U erE3eki 3,715 3722' 7' 6 Isolat U er[3eWn 3,723' 3J25' 2' 4 S zii DST U erBeli~~ 3,800' 3~828' 28' 6 Isola~ed a ~ u~ so a Mdc-e Beli 3,948 3 58' Id 8 Isolated Mid~eE3eli 4,008' 4016' 8' 4 Isolated M e Belu 4,096 4,1 16' 20' Isolat M~ eDel~~ 4, 4210' 8 Is~lated M e Belu~n 4,22T 423 ' 6' 4 Isola[ed e u~ s~ a e e u~a so a ower c u~n qz i im wer e u~n qz m wcr ~ u~n qt tm a are s~ a UppaTyme 5,57 5,600' 4' 8 Is~ at UppaTyrne 5,668 5,688' 2 4,$4 [s~ at U a T me t s~ at ppa yax s~ a so so LRU lA Schematic Current 11-9-09 .doc DRAWN BY: CVK REVISED: 11/9/09 Max Hole Angle =St~aighthok ,~ ,, Chevron FranclSCO Castro Chevron North America Exploration and Production -~~. Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE October 20, 2009 To: AOGCC Mahnken, Christine R 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 ~ ~ ~ ~ WELL:. LOG TYPE ~ ' ~~ ~ ~ RTES - ~aS. PDS, '~ SCwE LOG LATE ~~ E-LINE GD ~ ~Jo LRU 1A COMPLETION RECORD 5" 16-Sep-09 1 1 PDS SLU 41-33RD PERFORATION RECORD 5" 23-Jul-09 1 1 PDS TBU M-32RD RST SIGMA 5" 26-Nov-09 1 1 PDS, LAS, DLIS E'F3l~~ ®~t,~ ~. ~ ~VU~ ~~"~~~ I ~ -og~- ~~ j~~~~ ~`~ ~~ 5~ Please acknowledge~ceipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By; ~ (~1s - Oo5 • Page 1 of 1 Aubert, Winton G {DOA) From: Aubert, Vltnton G (DOA) Sent: Thursday, October 15, 2009 11:43 AM To: 'Kanyer, Christopher V' Subject: RE: LRU 1- Sundry 309-277, PTD 175-005 Ghris. Your requested Form 10-404 filing time e~ctensian is acceptable. Thanks for the update, Vtfinton Aubert AC?GCG 793-i 231 :~~~.~~ '~f i~~~ ,' ~' ~`• ~~~a From: Kanyer, Christopher V [mailto:Chris.Kanyer@chevron.can~ Sent: Thursday, Octc~ber i5, 20Q9 11:38 AM To: Au~ert, Winton G (DOA} Ce: Watsh, Chantal [Petrotechnical Resources of Alaska (PRA)]; Tyler, Steve L Subject: LRU 1- Sundry 309-277, PTD 175-005 Winton, The initial perf operations for LRU 1, Sundry 309-277, (PTD 175-O05) were completed on 9/16j09. Since these operations concluded, several attempts have been made to produce from the lower perf zones, but water and sand production have created issues with production equipment. We are currently waiting on additional replacement production equipment to flow the we11 and evaluate if there is a need to perForm the contingency operations on Sundry 309-277 and perforate up hole. Our proposal is to e~end the due date an additiona! 3Q days, to 11/16/09, for the required 10-404 in order to properly evaluate the open perforated intervals. Contingency operations could still be required due to water and sand production. If the well does produce from these open perfs, the well work for Sundry 309-277 wili be complete and a 1~-404 will be submitted promptly. Please let us know if you are agreeable to the e~ctension. Any questions you may have between 10/16- 10/25, when I will be out of office, can be answered by Chanta) Walsh 263-7627, the Reservoir Engineer over this project. Thanks, Chris Kanysr s • Technical Assistant Wellbore Maintenance Team Office: (907) 263-7831 CeIL (907) 25Q-0374 Chevron North America Exploration and Production MidcontinenUAlaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 10/15~2009 ~ • 6 ~ ~~ ~~ ~ : ~ r~` ~ ~ ~ a 6~ ~ ~ ~ ~ ~~ ' ~,' x ~r; y1 r ~ ` ~ ~ ~~ ~ ~ ~ ~ ~@~ ~~ ~~ ~~(y ~ gb~ ~§~ ~ @~F$ ~ ,~~ ~ SEAN PARNELL, GOVERNOR ~ ~ ~~ ~ ~ a.~ E'~:a ~ ~ ~ ~ ~~s%~ ~ ~: ~ '+.~ ~~ ~~i~~ f~'~a~ ~ F~~.~ A ~~ ~S~ ~l~ Alsi~ llr0a7 ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T COMI-IIS51O1~T ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 ~ FAX (907)276-7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California _`~ . . .. ____ P.O. Box 196247 .^ ~;~ ~ Anchorage, AK 99519 tr ~ '/~ Re: Lewis River, Undefined Gas, Lewis River 1„ ,.:. ., ~~~.r., a ~ ~i ~yi'~f~a,: ,~:~ ~ ,% Sundry Number: 309-277 ~'* Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~-- DATED this ~3 day of August, 2009 ~~~ Cathy P. Foerster Commissioner Encl. STATE OF ALASKA ~p~ ALAS~IL AND GAS CONSERVATION COMMI~N ~,~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 b•6G h Loo~ ~~~'~,~~~~.~~~~ r;i;i~ :~ ~~ 1Ca ,~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown n ~f~1 ^ Perforate ^~ ~~~~i;~a ?~~~&~' .~:.s. ~.~+ei~3~l~r~r~: i Alter casing^ Repair well ^ Plug Perforations ^~ ` Stimulate ^ Time Extensio¢~..~; ;., , Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ~, Exploratory ~ 175-005 • 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-283-20047-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~' Lewis River 1 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Poot(s): ADL0058801 (Lewis River Facility] 16.5 Lewis River / Undefined Gas • 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9,480 9,480 2,765 2,765 2,775 (cement) 2,765 (fill) Casing Length Size MD T1/D Burst Collapse Structural 48' 30" 48' 48' Conductor 363' 20" 363' 363' Surface 1,368' 13-3/8" 1,368' 1,368' 2730 psi 1130 psi Intermediate Production 8,147' 9-5/8" 8,147' 8,147' 6870 psi 4750 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" / 2-3/8" / 1-1/4"(heater) 6.4#N-80 / 4.6#N-80 / 2.3#L-80 5,760' / 4,691' / 1,956' Packers and SSSV Type: Packers and SSSV MD (ft): (4) Otis VST packers / Baker SSSV 2,098' ,3,883' , 4,676' , 5,470' / 297' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ ~ Service ^ 15. Estimated Date for 8/14/2009 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ , Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ ~ 6-7600 Date 8/5/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ ~/' 7 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: (Q - G~p 4,, . APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: g~~3~~ ~ Form 10-403 Revised 06/2006 ~ .,~.~ ~~ .~t~ .~ ~ ~~~~ ~R~GINAL _ .~ ~.~,~~: Submit in Duplicate Chevron • ~ ~ OBJECTIVE: • Lewis River Unit Well # LRU lA 8/5/09 , • Perforate upper Beluga sands. Contingency to isolate lower two perforated Beluga sands if water is produced. PROCEDURE SUMMARY: 1. RU slickline and pressure test lubricator to 250 psi low/2500 psi high. 2. RIH w/ GR and tag fill at 2,765' (+/-) RKB. /'~ 3. Attempt to bail fill to 2,775' (+/-) RKB. 4. Rig down slickline. 5. RU Eline and pressure test lubricator to 250 psi low/2500 psi high. 6. Perforate the following: • Upper Beluga 2,754' (+/-) - 2,764' (+/-) ' % ' Upper Beluga 2,718' (+/-) - 2,722' (+/-) 7. Rig down E-Line and turn well over to production. 8. Contingency Operations (if water is produced): a. RU slickline and pressure test lubricator to 250 psi low/2500 psi high. b. RIH w/ GR and tag fill at 2,775' (+/-) RKB. c. Rig down slickline. d. RU Eline and pressure test lubricator to 250 psi low/2500 psi high. e. Set CIBP at 2,700' (+/-) RKB. f. Rig down E-Line. g. RU slickline and pressure test lubricator to 250 psi low/2500 psi high. h. Attempt to swab fluid down to 2,650 (+/-). i. Rig down slickline. 9. RU Eline and pressure test lubricator to 250 psi low/2500 psi high. 10. Perforate the following: ^ Beluga 25-6 2,676' (+/-) - 2,68T (+/-) ~`' ^ Upper Beluga 2,663' (+/-) - 2,667' (+/-) 11. Rig down E-Line and turn well over to production. LRU lA REVISED BY: CVK 8-5-09 ! , Lewis River Well lA Current as of 9/8/06 RKB = 16.5' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 30" - LP Surf 48' Driven - 20" 94 H-40 F3utt 19.124 Surf 363' 26° 456sx " 54.5 12.615 Surf 943' U2° 17 1031 13-3/8 6l K-55 12.515 943' 1,368' - sx P-110 7,90T 8,14T 400sx S-95 8.681 6,985' 7,90T ca~ " N-80 4,502' 6,985' " ~~ry asoo• ro ssss~ 9-5/8 47 DV Collar 4,500' 4,502' 12-1/4 ~~SOsx N-80 8.681 Surf 4,500' Cmt ro SurP CBL Ratt 0 to 2580' Tubin 2-7/8" 6.4 N-80 Butt SC 2.441 Surf 4,691' 2-3/8" 4.6 N-80 Butt SC 1.995 4,691' S,760' 1-1/4" 23 L-80 CS H dril 1380 Surf 1,956' .IF.WF.LRY DF,TAIL NO. De th Len th ID OD Item 14.50' McEvo Dual Tubin Han er, 2-7/8" x 2-7/8" SLRT 1 I" SM 1. 29T 2.5' 2313 3.25 3.85 Otis "XXO" SSSV Landing Nipple P/N I 1 XXO 23100 2. 2 065' 337' 2313 3.75 Otis "XA" Sld Slve ' 12.0' 2.44 4.44 Otis Straight Slot Seal Assy w/ l 1' of Seals 3. 2,098 13 gl' 3.88 8.30 Otis "VST" Productian Pkrw/ 7.46' SBE ' 12.0' 2.44 4.12 Otis Shaight Slot Seal Assy w/ 11' of Seals 4. 3,883 13.8T 3.88 830 Otis "VST" Production Pkr w/ 7.52' SBE 5. 3,930' 335' 2313 3.75 Otis "XA" Sldg Slve 6 3,934' 4,382' 2o',~s',28', 34'.19'.19' 2.441 3.50 Carbide Blast Rings; 3934'-3965', 3994'-4025', 4091'~122', 4187'~324T4263'~294', 4352'~382' 7. 4,646' 334' 2313 3.75 Otis "XA" Sldg Slve ' 10.09' 2.44 4.12 Otis Straight Slot Seal Assy w/9' of Seals 8. 4,676 14.48' 3.88 830 Otis "VST° Production Pkr w/ 8.1 I' SBE 9. 4,691' 0.70' 1.94 3.52 Crossover, 2-7/8" BTC x 23/S" BTC ]0. 4,721' 132' 1.875 2.90 Otis "X" Profile Nipple ' ~0.19' 2.44 4.12 Otis Straight Slot Seal Assy w/9' of Seals 11. 5,470 14.47' 3.88 8.30 Otis "VST" Praduction Pkr w/ 8.09' SBE 12. 5,516' 3.34' 1.875 3.03 HES "XA" Sldg Slve 13. 5,729' 132' L875 2.90 HES "X" Profile Nipple 14. 5,760' 0.76' 1.94 6.05 WLEG PERFORATION INTERVAL Interval Accum. Zone Top Bhn Amt spf Comments Belu a 25-6 2,679' 2,687' S' 6 OPEN on 9/S/06 U erBel a 2,790' 2,792' 2' 2 S zd, Isolated U r Belu a 2,802' 2,819' 17' 6 Isolated U er Belu a 2,822' 2,828' 6' 6 Isolated O rBelu a 2,829' 2.832' 3' 2 S zd, [solated U r Belu a 3,084' 3,091' 7' 6 Isolated U rBelu a 3,092' 3,094' 2' 4 S id, DST U r Belu a 3,647' 3,651' 4' 4 S z'd, DST U r Bel a 3,715' 3,722' 7' 6 Isolated U r Bel a 3.723' 3 725' 2' 4 S i d, DST U r Bel a 3.800' 3.828' 28' 6 lsolated r e u Iso at M~ e Be u a _, 4 8 Iso ate Middle Belu a 4,008' 4,016' 8' 4 Isolated M~ e F3e uga Iso at M~ e Be uga Iso at M~ e Be uga , 7 Iso at ~ e Be uga , 7 Iso at ~ e e uga so a wer e uga qz uc on LowerBeluga 4,984' 4,994' 10' 8 Sqid, Pr uction wer e uga qz uc on pper yone so a Upper Tyone 5,576' S,600' 24' 8 Iso at Upper Tyone 5,668' S,688' 20' 4,8,4 Iso at Upper Tyone 5,707' S,7I5' 8 12 Isolated pper yone so a suae • - -.., - .1 1)ST IsotairJ LRU lA Schematic Current 9-08-06 .doc DRAWN BY: SLT REVISED: 8/4/09 Max Hole AnQle = ~ uNOCa~~b ~ Lewis River Well lA Current as of 9/8/06 PROPOSED RKB = 16.5' CASING AND TUBING DETAIL S1ZE WT GRADE CONN ID TOP BTM. Hole Size CM"C 30" - LP Surf 48' Driven - 20" 94 H-40 Butt 19.124 Surf 363' 26" 456sx " 54.5 12.615 Surf 943' " 1 1 13-3/8 6l K-55 12.515 943' 1,368' 17-1/2 sx 03 P-110 7,907' 8,147' S-95 8.681 6,985 7,90T 400sx CB~ e asoo' 55e8' 9-5/8" 47 N-80 4,502' 6,985' ]2-]/q" atry ro DV Collar 4,500' 4,502' 1150sx (Cmt to Sur~ N-80 8.681 Surf 4,500' CBL Ratry 0 to 2580' Tubin 2-7/8" 6.4 N-80 Butt SC 2.441 Surf 4,691' 2-3/8" 4.6 N-80 Butt SC 1.995 4,691' S,760' l-U4" 2.3 L-80 CS H dril L380 Surf 1,956' JEWELRY DETAIL NO. De th Len th ID OD Item 14.50' McEvo Dual Tubin Han er, 2 7/8" x 2-7/8" SLRT 11" SM l. 297' 2.5' 2313 325 3.85 Otis "XXO" SSSV Landing Nipple P/N 11 XXO 23100 2. 2,065' 33T 2313 3.75 Otis "XA" Sld Slve , 12.0' 2.44 4.44 Otis Straight Slot Seal Assy w/ I 1' of Seals 3. Z,pqg 13.81' 3.88 830 Otis "VST° Production Pkr w/ 7:46' SBE 3A. 2.700'(~/-) 75' Ilallibw~on3-7%3~CIBP-l?u~uu~ •n~~r • ' ~2'0' 2.44 4.12 Otis Straight Slot Seal A I 1' of Seals 4. 3,883 13.ST 3.88 830 O[is "VST" Production Pkr w/ 7.52' SBE 5. 3,930' 335' 2313 3.75 Otis "XA" Sldg Slve 6 3,934' 4382' 2o',ts',2s', 34',19',19' 2.441 3.50 Carbide Blast RingS 3934'-3965', 3994'~1025', 409P~122',4187'~324T4263'~294' 4352'-4382' 7. 4,646' 334' 2.313 3.75 Otis "XA" Sldg Slve ' 10.09' 2.44 4.12 Otis Straight Slot Seal Assy w/9' of Seals 8. 4,676 14.48' 3.88 830 Otis "VST" Production Pkr w/ 8.l 1' SBE 9. 4,691' 0.70' 1.94 3.52 Crossover, 2-7/8" BTC x 2-3/8" BTC 10. 4,721' 132' 1.875 2.90 Otis "X" Profile Nipple ' ~0.19' 2.44 4.12 Otis Straight Slot Seal Assy w/9' of Seals 1 l. 5,470 14.4Y 3.88 830 Otis "VST" Production Pkr w/ 8.09' SBE 12. S,S l6' 334' 1.875 3.03 HES "XA" Sldg Slve 13. 5,729' 1.32' 1.875 2.90 HES "X" Profile Nipple 14. 5,760' 0.76' 1.94 6.05 WLEG PERFORATION INTERVAL Inoerval Acc~m. Zone Top Btm Amt spf Comnents U er Belu 2bh3' +/- 2(~(~7' +/- J' 6 Pro osed Dclu 25fi 2~7fi' +/- 2687' +/- 11' 6 Pro ~ed Belu 25-6 2679 2687' S' 6 OPENon9/8/06 l!i~crl3elu 171N' +/_ Z'nZ' +/- d' 6 ProiaseJ I! i~er t3elu 2,75J' +/- 2 764' +/_ ~p' 6 Pru ~aseJ U a Be ~ 790' 2,792' 2' 2 S z'd, Isdat U erBeV 2802' 2 19' IT 6 Isolated U erBeV 2822' 28' 6' 6 I late U erBeu 2,829 2$32' 3' 2 S z'd, Isolated U erBeki 3,084' 3,091' 7' 6 Isolated U erBeW 3,092 309i' 2' 4 S zd, DST U erBe6 3,61P 3651' 4' 4 S z'd DSC U erBeW 3,715 3,722' 7' 6 I~lated U erBeW 3,723' 3,7Z5' 2' 4 S zd, DST U erBeW 3,80d 3$28' 28' 6 I~lated U~ F3e i~ , 50' %' 6' Isu at e u so a Mid~e E3eli 4,008 4,016' 8' 4 I~lated Md e Belu~ ,096' 4,116' 8 I~lat e u~ so a M e B t~ 4, T z3 ' 6' 4 I:ulat Mid~e Belu~ 4, 8 4Z87' 9' 8 Is~lated wa e uta qz ~rn LowerBclu 4484' 4 93' 10 8 S z'd, Raductim wer c u~ qz im pper yrne su a U aT me 5,57 5 24' 8 l~lated Uppa"Tyrne 5, 5;6 20' 4,$4 I~lated UppaTya~e 5,70T 5,715' 8' 12 Is~lat a me so a so LRU lA Proposed Schematic 8-4-09 .doc DRAWN BY: CVK REV[SED: 8/4/09 Max Eiole Angle =StraiQhthole Chevron ~ncisco Castro Chevron North Ar~rica Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: FCBN@chevron.com December 3, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 ~~ 3~2i~ ~, ~ rJ~ PERMIT # API NUMBER WELL LOG TYPE SCALE LOG DATE INTERVAL RU~I ' B- ~'L~1 CD PJOTES - ~~ Ln~ ~cD rr LINE ~ u1S, I j PDS, -- j - - COMPLETION RECORD HALLIBURTON 175-005- BRIDGE PLUG, 2000 - 0 502832004700 LRU 1A CEMENT RETAINER 5" 1-Se -06 3911 1 1 1 1 PDS C MPLETION 178-075- R CORD TTS 2 7; 8" 2280 - 502832996101 LRU C1 UBING PATCH 5" 8-Sep-06 2550 1 1 1 1 PDS COMPLETION RECORD 2" POWERJET OMEGA 175-005- 6 SPF, 60 DEGREE 2500 - 0 502832004700 LRU 1A PHASED 5" 9-Se -06 2750 1 1 1 1 PDS COMPLETION RECORD 2" POWERJET OMEGA 6 SPF 2 7/8" TTS 201-168- LRU RETRIEVABLE 11-Aug- 5600 - 0 502832006101 C1 RD BRIDGE PLUG 5" 06 6013 1 1 1 1 PDS l~S- 005 ~i 5~3~r' ~ ~ 5~~35 ~~~~ DE(; 2 1 2~0? ~_J Please acknowledge receipt by signing and returning one copy of thls~ tl~r~srrrtttal or FA~~ to 907 263 7828. Received 8 Date: ~ ~~~;' ~:4~ _ . . . Chevron III Kevin A. Tabler Manager, Land & Government Affairs MidContinent; Alaska Chevron North America Exploration and Production 909 West 9th Avenue P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7600 Fax 907 263 7698 Email tablerk@chevron.com February 13, 2007 Mr. Kevin Banks, Acting Director Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, AK 99501-3560 LEWIS RIVER UNIT STATE OF ALASKA REVISED THIRTY-SECOND PLAN OF DEVELOPMENT SCANNED MAR 2 9 2007 AND OPERATIONS Dear Mr. Banks: Pursuant to the current State of Alaska regulations governing submittal and approval of Unit Plan of Development and Operations, 11 AAC 83.343/11 AAC 83.346, Union Oil Company of California, a Chevron company, as Unit Operator, submits the following Revised Thirty-second Plan of Development and Operations for the Lewis River Unit Area: I. PERIOD This Plan shall cover the period from May 7, 2007 to May 6, 2008. II. WELL WORK REVIEW A. THIRTY-FIRST PLAN REVIEW ~ \,\S-COS- LRU 1-A was recompleted and flow tested at 2.4 MMCFPD in September 2006. The well was shut-in for the winter. Facility modifications are needed prior to putting this well onto production. ~ ~O\- \<.0 % A thru-tubing gravel pack was installed in August 2006 in LRU C-1RD. Attempts to swab in the well were terminated in October 2006. The well would not maintain flow. B. THIRTY-SECOND PLAN POTENTIAL WORK Well C-1RD will be evaluated for an acid stimulation to remove formation damage that may have occurred during the installation of thru-tubing gravel pack. The acid stimulation may occur during the Thirty-second plan period. Development of the Beluga and Tyonek potential in the Lewis River Unit will depend on the results of additional flow testing of the LRU 1-A in early spring 2007, and the possible drilling of a new well in 2008/2009. Union Oil Company of California I A Chevron Company http://www.chevron.com . . Mr. Kevin Banks, Acting Director February 13, 2007 Page 2 Long Term Development Plan Due to the remote location of the gas fields on the west side of the Cook Inlet, a winter drilling program may strand a drilling rig on the west side for the winter. The economics of the development opportunities at the west side properties cannot support the added cost of winter time, remote location drilling, and the high cost of having a drilling rig and all its ancillary equipment on standby for months. If a large enough work program can be developed and we determine that it can be safely and economically implemented through the winter months, we may be able to overcome the added burden that the ADF&G work season restriction presents. Union is working on a west side drilling/workover program that would include project(s) at the Lewis River Unit. Any drilling program on the west side of Cook Inlet must coordinate with drilling activity anticipated at other nearby west side fields. No one Unit alone can absorb the mob, demob and standby cost incurred by a stand alone operation. The largest gas field on the west side is the Beluga River Unit. It is anticipated that a rig will be mobilized to conduct in-field drilling activities in this Unit in the 2008/2009 timeframe, which would be the earliest that drilling activity is contemplated on the west side. With this activity, there may be an opportunity to utilize this rig in conjunction with other drilling activity on the west side. The timing of the Beluga River Unit drilling activity is expected to coincide with the Beluga River operator's market requirements. Regardless of the activity at the Beluga River Unit, Union's multi-well, multi-unit west side development program evaluation has a similar timing profile, e.g., planning will occur in 2007 with budgeting/drilling in 2008-2009. Market conditions will have the biggest influence and ultimately dictate drilling activity on the west side. Whether or not Agrium can secure a sufficient volume of gas to maintain seasonal operation of its Nitrogen Fertilizer Plant, the outcome of Marathon and ConocoPhillips LNG export license extension application and commitments to the unfilled utility markets are the market unknowns at this time. The range of possible outcomes of these events alone will have a significant influence and impact on the timing of any west side development thus, making long range commitment forecasting difficult at best to plan. Union Oil Company of California I A Chevron Company http://www.chevron.com . . . Mr. Kevin Banks, Acting Director February 13, 2007 Page 3 III. PRODUCTION PLAN . Cumulative Gas production from Lewis River Field for the period January 1, 1991 through December 31, 2006 is as follows: Date Mo-Yr 12/31/91 12/31/92 12/31/93 12/31/94 12/31/95 12/31/96 12/31/97 12/31/98 12/31/99 12/31/00 12/31/01 12/31/02 12/31/03 12/31/04 12/31/05 12/31/06 LRU 1-A MMCF 1,831 2,384 2,696 2,884 2,984 3,070 3,115 3,201 3,435 3,560 3,731 3,858 3,930 3,965 3,965 3,965 LRU C-l(& RD) MMCF 5,238 5,390 5,461 5,516 5,543 5,571 5,592 5,608 5,620 5,628 5,679 6,449 6,952 7,286 7,610 7,628 Total MMCF 7,069 7,774 8,157 8,400 8,527 8,641 8,707 8,809 9,055 9,188 9,410 10,307 10,882 11,251 11,575 11,593 The Lewis River D-l well is shut in and is not expected to be used for water disposal during the upcoming plan period. Injection to date is as follows: Date Year 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 Yearly Inj. BBLS 4,601 3,144 4,203 2,578 2,769 6,571 4,321 1,839 1,173 2,408 1,481 2,486 993 1,672 o o Days on Inj. Per Year 67 21 34 58 32 78 36 20 20 34 32 67 24 70 o o Union Oil Company of California I A Chevron Company http://www.chevron.com . . Mr. Kevin Banks, Acting Director February 13, 2007 Page 4 IV. SURFACE AND FACILITY OPERATIONS A. THIRTY-FIRST PLAN REVIEW Unocal was notified by the Alaska Department of Environmental Conservation (Solid Waste Program) that all post closure water quality monitoring requirements for the Lewis River 13-2 reserve pit had been met and no additional water quality monitoring was required. B. THIRTY-SECOND PLAN POTENTIAL WORK Due to the successful recompletion of LRU 1-A, during the Thirty-second plan period, engineering will be completed to determine the necessary facility work to return this well to production. This work may include the installation/replacement of facilities such as compression, dehydration, piping and tanks during this plan period. Such work is contingent upon the results of additional flow testing of this well in early spring 2007. Union, as Unit Operator, reserves the right to propose modifications to this Plan should conditions so warrant; however, no modifications will be made without first obtaining permission from the appropriate governmental agencies. Very truly yours, UNION OIL COMPANY OF CALIFORNIA By: K n A. Tabler Manager, Land & Government Affairs APPROVED: ALASKA DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas This day of , 2007 By: KAT:GAO:dma cc: Gary Orr, CVX Daniel T. Seamount, AOGCC Dave Whitacre, CVX Union Oil Company of California I A Chevron Company http://www.chevron.com · STATE OF ALASKA ALAS~ILAND GAS CONSERVATION COMMleN OCT 1 6 200S REPORT OF SUNDRY WELL OPERA TIO_a Oil & Gas Cons. - 1. Operations Abandon Performed: Alter Casing 0 Change Approved Program 0 2. Operator Name: Union Oil Company of California 3. Address: Repair Well Pull Tubing 0 Opera!. Shutdown 0 PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 16.5 8. Property Designation: Lewis River Unit ~ >!!eO( ~I"A z..~ .c¿". 11. Present Well Condition Summary: Total Depth measured true vertical Effective Depth measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 48' 363' 1,368' 8,147' Perforation depth: 9480 feet 9480 feet 2775 feet 2775 feet Size 30" 20" 13-3/8 " 9-5/8" Measured depth: 2,679' to 2687' ' True Vertical depth: 2,679' to 2687' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Upper Tyonek 5528' - 5764' \ Middle Beluga 3948' - 4369' \ Upper Beluga 2790' - 3856' Treatment descriptions including volumes used and final pressure: "Lay-in" 27 bbls of LXT cmt from 3152' to 2790'. Circulated 42 bbls of LXT cmt in tbg x csg annulus from 2769' to 2118'. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf o 0 o 2400 15. Well Class after work: Exploratory 0 16. Well Status after work: OilO Gas 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Temp Survey depicting TOC Daily Report of Well Operations Daily Operation Summary Contact Steve Tyler 907263-7649 Printed Name Tim Brandenburg Signature "L. Form 10-404 Revised 04/2006 t\ t: tA:: I Vi:: U Plug Perforations .¡ Perforate New Pool 0 Perforate 0 4. Well Class Before Work: Development 0 Stratigraphic 0 Stimulate Ot !P" Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 175-005 6. API Number: 50-283-20047-00 9. Well Name and Number: LRU-01 L/Z.U 01 P /p,z."3.t:Þ1t. 10. Field/Pool(s): Lewis River / Beluga, Tyonek Exploratory 0 Service 0 Plugs (measured) 3910',2775' Junk (measured) MD 48' 363' 1,368' Collapse o 520 psi 1,130 psi TVD 48' 363' 1,368' Burst o 1,530 psi 2,730 psi 8,147' 4,760 psi ~é~(;A~~EÐ 8,147' f'. Fy éíf\r\p¡ IU ~: t.......'""''-' 6,870 psi 1-1/4" 2-7/8" 2-3/8" L-80 N-80 N-80 _..~ ._.~.-._. _,.,"'H~_. 1,938' 4,691' 5,760' (4) Otis "VST" 2098'; 3883'; 4676'; 5470' Water-Bbl o o Casing Pressure o o Tubing Pressure o 1020 Development 0 Service 0 WAG 0 GINJ 0 WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: 306-158 o Title Drilling Manager Phone 907263-7657 Date 10/11/2006 /O·'Z.3·o~ - ~ubmit Original Only ~/6>/~/~ R8DMS 8Ft NOV 0 6 2006 í.°h\ ell Name LRU 1A Primary Job Type Recompletion Jobs Primary Job Type Recompletion Daily Operations 8/28/2006 00:00 - 8/29/200600:00 perations Summary Mobe/Spot solid control equip, & mise support equip to location. 8/29/2006 00:00 - 8/30/2006 00:00 Operations Summary Mobe/Spot CT equipment onto pad. Remove well house. Pressure test BOPE. SDFN. 8/30/200600:00 - 8/31/200600:00 Operations Summary SIMOPS. PJSM. Cintinue RU. Accept CT @ 16:00 hrs. RIH w/ CT @ 30 fpm circ 1.7 bpm. Cleanout to 3930'. No solids in returns. No further progress past 3930'. Pump sweep. CBU. Jello mud type solids on BU. 2nd sweep BU clean. POOH. Secure well. 8/31/2006 00:00 - 9/1/2006 00:00 Operations Summary SIMOPS. PJSM. Set CIBP @ 3910' on Eline. Attempt to establish injection rate & pressures into upper Beluga. No Joy. Suspend operations to reformulate forward plan. 9/1/2006 00:00 ·9/2/2006 00:00 Operations Summary PJSM. Eline convey tbg punch gun. perf tbg @ 3152' - 3162' & 2790' - 2795'. RIH w/1.5" CT. Reciprocate CT between 2790' thru 3152' three times. "Lay-in" 27 bbls of LXT cmt from 3152' to 2790'. PU to 2450'. Pump 5 bbls of Biozan. CBU. RI to 2790' while circulating @ max rate of 1.7 bpm to polish TOC. POOH. Trap 300 psi on tbg. SDFN. 9/2/2006 00:00 ·9/3/2006 00:00 Operations Summary SIMOPS & PJSM. Clean surface equipment. RIH w/ Eline. Tag @ 2611 '. POOH RD Eline. Pressure test tbg to 1510 psi. Bled to 1400 psi in 30 min. 9/3/200600:00 - 9/4/2006 00:00 Operations Summary SIMOPS & PJSM. RU Slickline. RI bailed contaminated cement stringers from 2612' to 2781'. RD Slickline. RU Eline. RI Punch tbg from 2769' to 2764'. Gained 300 psi. Attempt to jug test. No Joy, too much compression. Miss-run on Weatherford retainer, no oil in setting tool. . 9/4/2006 00:00 ·9/5/2006 00:00 Operations Summary RI set cmt retainer w/ slide valve @ 2764'. RI punch tbg from 2119' to 2124'. Gained 100 psi. Rest crews. Tbg @ 1500 psi. Lubricate fluid into well. tbg pressure reduced to 1000 psi. RIH w/ CT. Circulate gas from well. RI stab into retainer @ 2764'. CBU. PU above retainer. CBU. Stab back into retainer. Pump/circulated 45 bbls (225 sx) of LXT cmt. Displace CT. PU above retainer. CBU. Recovered 3 bbls. ---42 bbls in place--- Spot 10 bbls of9% KCI. PU to 2500'. 9/5/200600:00 ·9/6/2006 00:00 Operations Summary With CT @ 2500' jet tbg dry. recovered 22 bbls. POOH. Trap 850 psi on tbg. 9/6/2006 00:00 ·9/7/2006 00:00 Operations Summary PJSM & SIMOPS Meetings. RU Slickline. gauge tbg w/2" spent dummy gun to 2762'. POOH RD. 917/200600:00·9/9/200600:00 Operations Summary Demobe accessory equipment from pad. Clean Pad. 9/8/200600:00 - 9/10/2006 00:00 ~ Operations Summary SIMOPS & PTSM. RU Eline. Arm 8' x 2" 6 spf 60 degree PowerJet Omega gun. RIH perforate 2679' - 2687'. Pressure increased from 790 psi to 1018 psi while' POOH. RD. Flow test well @ 2.4 mmcfpd w/1 030 psi. 9/10/200600:00 - 9/11/200600:00 Operations Summary Turn well over to production. Finished cleaning pad. FINAL Report. ,ft¡;i,< ··,',Mik"'~.: ..,,'" RKB =16.5' SIZE WT GRADE 1'01> 30" LP Surf 48' 20" 94 H-40 Butt 19.124 Surf 363' 13-3/8" 54.5 K-55 12.615 Surf 943' 61 12.515 943' 1368' P-ll 0 7907 8147' S-95 8.681 6985 7907' 9-5/8" 47 N-80 4502 6985' 12·1/4" 4500 4502 N-80 S.681 Surf 4500 Tubin 2-7/8" 6.4 N-80 Butt SC 2.441 Surf 4691' 2- 3/S" 4.6 N-SO Butt SC 1.995 4691' 5760' 1-1/4" 2.3 L-SO CS H drii 1.380 Surf 1938' JEWELRY DETAIL LRU lA Schematic Current 9-08~06 .doc NO. D~íl! Lel!J,l;tl! m OD hem 14.50' McEvoy DualTubing Hanger, 2-7/8" x 2-7/8" SLRT 11" 5M I. 297' 2.5 2.313 3.25 Otis "XXO" SSSV Landing Nipple 3.85 (PIN 1 I XXO 23100) 2. 2065 3.37 2.3 13 3.75 Otis "XA" Sldg Slve 3. 2098 12.0 244 444 Otis Straight Slot Seal Assy wIll' of Seals 13.81 3.88 8.30 Otis "VST" Production Pkr wI 7.46' SBE 4. 3883 12.0 2.44 4.12 Otis Straight Slot Seal Assy wIll' of Seals 13.87 3.88 8.30 Otis "VST" Production Pkr wi 7.52' SBE 5. 3930 3.35 2.3 13 3.75 Otis "XA" Sldg Slve 6. 3934' 20',t8',28', 2.441 3.50 Carbide Blast Rings; 3934' 3965', 4382' 34',19',]9' 4091'-4122',4187'-4247'4263' 4294', .o~~, 7. 4646 3.34 2.313 3.75 Otis "XA" Sldg Slve 8. 4676 10.09 244 4,12 Otis Straight Slot Seal Assy wI 9' of Seals ]448 3.88 8.30 Otis "VST" Production Pkr wI 8.11' SBE 9. 4691 0.70 1.94 3.52 Crossover, 2-7/8" BTC x 2-3/8" BTC 10. 4721 1.32 1.875 2.90 Otis "X" Profile Nipple ]] 5470 10.19 244 4.12 Otis Straight Slot Seal Assy wI 9' of Seals ]4.47 3.88 8.30 Otis "VST" Production Pkr wI 8.09' SBE ]2. 55]6 3.34 1.875 3.03 HES "XA" Sldg Slve 13. 5729 132 ].875 2.90 HES "X" Profile Nipple ]4. 5760 0.76 1.94 6.05 WLEG DRAWN BY: SLT Pressure (psia) 800 850 900 950 1000 1050 1100 1150 1200 0 100 200 300 400 500 600 100 800 900 1000 1100 0 1200 :E ::¡:;- 1300 CD ..e 1400 - '5 1500 C. ~ 1600 1100 1800 1900 2000 2100 2200 2300 2400 2500 2600 2100 2800 52 54 56 58 60 62 64 66 68 70 72 Temperature (Deg. F) Report date: 10/10/2006 Current as: of 9/8/06 RKB= 16.5' SIZE WT GRAOE 30" LP 20" 94 H-40 13-3/8" 54.5 K-55 61 P-IIO S-95 9-518" 47 N-80 N-80 Butt CASING AND TUBING DETAIL m TOP BTM, Surf 48' Surf 363' Surf 943' 943' 1368' 7907 8147' 6985 7907' 4502 6985' 4500 4502 Surf 4500 19.124 12.615 12.515 Hole Size Driven 26" CMT 456sx 1031 sx 6.4 4.6 2.3 8.681 400sx CEL Ratty 4500' to 5568' 8.681 TubilJ 2-7/8" 2-3/8" 1-1/4" CBL N-80 N-80 L-80 Butt SC Butt SC CS H dril 2.441 1.995 1.380 Surf 4691' Surf 4691' 5760' 1938' Ratl NO. D~II¡ Lel!Rfl¡ m OD Hem 14.50' McEvoy Dual Tubing Hanger, 2-7/8" x 2-7/8" SLRT II" 5M I. 297' 2.5 2313 3.25 Otis "XXO" SSSV Landing Nipple 3.85 (PIN II XXO 23100) 2. 2065 3.37 2313 3.75 Otis "XA" Sldg Slve 3. 2098 12.0 2.44 4.44 Otis Straight Slot Seal Assy wi II' of Seals 13.81 388 830 Otis "VST" Production Pkr wi 7.46' SBE 4. 3883 12.0 2.44 4.12 Otjs Straight Slot Seal Assy wi II' of Seals 13.87 388 830 Otis "VST" Production Pkr wi 7.52' SBE 5. 3930 335 2.313 3.75 Otis "XA" Sldg Slve 6. 3934' 20',18',28', 2.441 3.50 Carbide Blast Rings; 3934'-3965', 3994'-4025', 4382' 34',19',19' 4091 '-4122', 4187'-4247'4263'-4294', 4352'-4382' 7. 4646 334 2313 3.75 Otis "XA" Sldg Slve 8. 4676 10.09 2.44 4.12 Otis Straight Slot Seal Assy wi 9' of Seals 14.48 3.88 830 01is "VST" Productjon Pkr wi 8.11' SBE 9. 4691 0.70 1.94 3.52 Crossover, 2-7/8" BTC x 2-3/8" BTC 10. 4721 1.32 1.875 2.90 Otis "X" Profile Nippk II. 5470 10.19 2.44 4.12 Otjs Straight Slot Seal Assy wi 9' of Seals 14.47 3.88 8.30 Otjs "VST" Production Pkr wi 8.09' SBE 12. 5516 334 1.875 3.03 HES "XA" Sldg Slve 13. 5729 1.32 1.875 2.90 RES "X" Profile Nipple 14. 5760 076 1.94 6.05 WLEG JEWELRY DETAIL PERFORATION INTERVAL LRU IA Schematic Current 9-08-06 .doc DRA WN BY: SL T - Re: Revised Procedure for LRU 1A Sundry# 306-158 e e Steve, As you indicated, the intent is still to place cement to provide isolation. been modified since you cannot pump into the perforations. Your modification is acceptable. Good luck with the work. Tom Maunder, PE AOGCC \ 'ì. S .... 'C::() Ç"" The placement method has SCANNED fmG 31 20D5 Tyler, Steve L wrote, On 9/1/2006 2:27 PM: Tom As per our conversation, we had to revise our forward plan due to our inability to establish an injection rate into the upper Beluga sands. Union Oil Company of California (Office: (907) 263-7649 (Cell: (907) 350-6295 (Home: (907) 696-1837 (Fax: (907) 263-7389 .Email: tvlersl@chevron.com lofl 9/5/2006 8:37 AM e e WestS ide Field Lewis River Unit LRU #1A \~s-a() $""" pecial Concerns: · Schlumberger documentation on the 2" Omega gun depicts gun swelling, in gas, out to 2.31" OD. Otis "XXO" SSSV Nipple @ 297' is 2.31" ID. · Need to ensure there is fluid across the desired perf interval, when utilizing Omega gun. · Will be "laying-in" 350' of cement to isolate existing perfs from 25-6 perfs. Volume calculation assumes placement of cement in tbg x csg annulus over the 350' interval. · Possible to have cement returns at surface If unable to achieve displacement of cement in tbg x csg annulus. · Will perform a circulating placement of cement in tbg x csg annulus on 2nd cement job. · Will need a variance to NOT run the flapper/check valve on the 2nd cmt job through the retainer w/ slide valve. · Fluids, that will be exposed to 25-6 sand, will be 9% KCI brine. Workover Summary: 1. EL- RU Eline. RI w/ 10' tbg punch gun to 3152' Perf tbg. RI w/ 2nd 5' tbg punch gun to 2790'. Perf tbg. POOH. RD Eline . Double 2. CT- PUMU cement nozzle BHA. Reference SOP CT-105 SOPCT-l05 icons to open me 3. CT- RI H to 3155'. Lay-in 27 bbls of cement (2 bbls over calculated vol.), while taking returns out CT x tbg annulus to 2780'. PU to 2430'. Pump 5 bbls of Bioxan. CBU. 4. CT- RI pumping max rate. Polish TOC to 2790'. POOH. Stand injector head back. WOC 24 hrs. 5. EL- RU Eline. RI w/ 5' tbg punch gun. Tag TOC @ 2790'. PU Perftbg @ 2780'. Jug test wellbore to 1500 psi. RI set Weatherford retainer w/ slide valve @ 2775'. RI H w/ 5' tbg punch gun. Punch tbg @ 2115'. POOH. RD Eline 6. CT- RIH stab stinger into retainer @ 2760'. Establish circulation rates & pressures. 7. CMT - Mix 45 bbls of LXT cement blend (2 bbls over calculated vol.). Pump/circulate cmt down CT while taking returns out CT x tbg annulus. Displace cmt to retainer. PU above retainer. Pump 5 bbls of Bioxan. CBU. Spot 10 bbls of 9% KCI brine on btm. MASP tbg= 4000 psi, MASP csg= 2500 psi. 8. CT- PU to 2500'. Jet tbg dry w/ Nz while POOH. Trap 800 psi at surface. RD injector head. 9. WL- RU slickline onto CT BOPE. RIH w/ temp survey tool to 2775'. POOH logging. RD. 10. - Release CT unit to 'Turn-Keyed Demobe". WOC 72 hrs. 11. EL- RU Eline. RIH with perforating guns. Perforate Beluga 25-6 sand as depicted on the "LRU #1A Final Approved Perforation Sheet July 2006". RD Eline. 12. - Turn well over to production e e Lewis River \1--., c:-..r Well 1A . \.5-Q'U:> CURRENT as of 1117/04 CASING AND TUBING DETAIL RKB= 16.5' SIZE WT GRAllE CONN In TOP BTM. Hole SLœ CMT 30" 1]> Surf 48' Driven 20" 94 H-40 Butt 19.124 Surf 363' 26" 456sx 13-3/8" 54.5 K-55 12.615 Surf 943' 17-1/2" 1031sx 61 12.515 943' 1368' P-ll 0 7907 8147' 400sx S-95 8.681 6985 7907' eBL N-80 4502 6985' Ratty 4500' to 5568' 9-5/8" 47 4500 4502 12-1/4" 1150sx N-80 8.681 Surf 4500 erot to Surf CBL Ratt 0 to 2580' Tubin 2-7/8" 6.4 N-80 Butt SC 2.441 Surf 4691' 2-3/8" 4.6 N-80 Butt SC 1.995 4691' 5760' 1-1/4" 2.3 L-80 CS H dril 1.380 Surf 1938' JEWELRY DETAIL Fill tagged @ 4582' on 10/4/04 LRU 1A Current.doe NO, Depth Lcnoth m 00 Itt~m 14.50' McEyoy Dual Tubing Hanger, 2-7/8" x 2-7/8" SLRT II" 5M 1. 297' 2.5 2.313 3.25 Otis "XXO" SSSV Landing Nipple 3.85 (PIN 11 XXO 23100) 2. 2065 3.37 2.313 3.75 Otis "XA" Sldg Slye 3. 2098 12.0 2.44 4.44 Otis Straight Slot Seal Assy wi II' of Seals 13.81 3.88 8.30 Otis "VST" Production Pkr wi 7.46' SBE 4. 3883 12.0 2.44 4.12 Otis Straight Slot Seal Assy wi II' of Seals 13.87 3.88 8.30 Otis "VST" Production Pkr wi 7.52' SBE 5. 3930 3.35 2.313 3.75 Otis "XA" Sldg Slye 6. 3934' 20'.18'.28'. 2.441 3.50 Carbide Blast Rings; 3934'-3965', 3994'--4025', 4382' 34'.19',19' 4091 '--4122',4187'--4247'4263'--4294',4352'--4382' 7. 4646 3.34 2.313 3.75 Otis "XA" Sldg Slye 8. 4676 10.09 2.44 4.12 Otis Straight Slot Seal Assy wi 9' of Seals 14.48 3.88 8.30 Otis "VST" Production Pkr wi 8.11' SBE 9. 4691 0.70 1.94 3.52 Crossoyer, 2-7/8" BTC x 2-3/8" BTC 10. 4721 1.32 1.875 2.90 Otis "X" Profile Nipple 11. 5470 10.19 2.44 4.12 Otis Straight Slot Seal Assy wi 9' of Seals 14.47 3.88 8.30 Otis "VST" Production Pkr wi 8.09' SBE 12. 5516 3.34 1.875 3.03 HES "XA" Sldg Slye 13. 5729 1.32 1.875 2.90 HES "X" Profile Nipple 14. 5760 0.76 1.94 6.05 WLEG PERFORA TION INTERVAL Interval ·Top Dim 2,790' 2,792' 2,802' 2,819' 2,822' 2,828' 2,829' 2,832' 3,084' 3,091' 3,092' 3,094' 3,647' 3,651' 3,715' 3,722' 3,723' 3,725' 3,800' 3,828' 3,8 3, 6 Accum. spf 2 6 6 2 6 4 4 6 4 6 DRAWN BY: SLT REVISED: 3/21/2006 e e Lewis River Well 11\ PROPOSED \~S- -00) CASING AND TUBING DETAIL RKB= 16.5' S.lZE WT GRAll~: CONN In TOP HTM. Hole Sizt, CMT 30" LP Surf 48' Driven 20" 94 H-40 Butt 19.124 Surf 363' 26" 456sx 13-3/8" 54.5 K-55 12.615 Surf 943' 17-1/2" 1031sx 61 12.515 943' 1368' P-IlO 7907 8147' 400sx S-95 8.681 6985 7907' CBL N-80 4502 6985' Ratty 4500' to 5568' 9-5/8" 47 4500 4502 12-1/4" 1150sx N-80 8.681 Surf 4500 Cm! to Surf CBL Rat! 0 to 2580' Tubin 2- 7 /8" 6.4 N-80 Butt SC 2.441 Surf 4691' 2-3/8" 4.6 N-80 Butt SC 1.995 4691' 5760' 1-1/4" 2.3 L-80 CS H dril 1.380 Surf 1938' JEWELRY DETAIL LRU 1A Proposed. doc NO. Ih,pth IA'lJoth .10 00 Item 14.50' McEvoy Dual Tubing Hanger, 2-7/8" x 2-7/8" SLRT 11" 5M I. 297' 2.5 2.313 3.25 Otis "XXO" SSSV Landing Nipple 3.85 (pIN 11 XXO 23100) 2. 2065 3.37 2.313 3.75 Otis "XA" Sldg Slve 3. 12.0 2.44 4.44 Otis Straight Slot Seal Assy wI II' of Seals 2098 13.81 3.88 8.30 Otis "VSr' Production Pia wI 7.46' SBE 4. 3883 12.0 2.44 4.12 Otis Straight Slot Seal Assy wI II' of Seals 13.87 3.88 8.30 Otis "VST" Production Pia wI 7.52' SBE 5. 3930 3.35 2.313 3.75 Otis "XA" Sldg Slve 6. 3934' 20',18'.28'. 2.441 3.50 Carbide Blast Rings; 3934'-3965', 3994'-4025', 4382' 34',19'.19' 4091 '-4122',4187'-4247'4263'-4294',4352'-4382' 7. 4646 3.34 2.313 3.75 Otis "XA" Sldg Slve 8. 4676 10.09 2.44 4.12 Otis Straight Slot Seal Assy wI 9' of Seals 14.48 3.88 8.30 Otis "VST" Production Pia wI 8.11' SBE 9. 4691 0.70 1.94 3.52 Crossover, 2-7/8" BTC x 2-3/8" BTC 10. 4721 1.32 1.875 2.90 Otis "X" Profile Nipple II. 5470 10.19 2.44 4.12 Otis Straight Slot Seal Assy wI 9' of Seals 14.47 3.88 8.30 Otis "VST" Production Pia wI 8.09' SBE 12. 5516 3.34 1.875 3.03 HES "XA" Sldg Slve 13. 5729 1.32 1.875 2.90 HES "X" Profile Nipple 14. 5760 0.76 1.94 6.05 WLEG PERFORATION lNTERV AL Amt 2' Accorn. spf 2 6 6 2 6 4 4 6 4 6 6 DRAWN BY: SLT REVISED: 3/21/2006 e e FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 115- ro~ Re: Lewis River Unit, Undefined Gas Pool, LRU-01 Sundry Number: 306-158 , ~" ~'?-'iñ ",~, (t', '~\í'-~",~¡;"'t) ~\¡¡1~"0'i1"'" ( f1!I',: r,\ C," '':ù I,.;Ü \u ~ {... Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Com,mission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this cg day of May, 2006 Encl. ÐT.J S/¿,4. STATE OF ALASKA (,{t1~"S,.g,J¡", k AlA~ Oil AND GAS CONSERVATION COMM.ON ~ APPLICATION FOR SUNDRY APPROVAL!i;;)i':; 20 AAC 25 280 1. Type of Request: Abandon U Suspend 0 Operational shutdown U Perforate ~ . Waiver U , Other U Alter casing 0 Repair well 0 Plug Perforations [] , Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development [] . Exploratory 0 175-005 . 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 196247, Anchorage, AK 99519 50-283-20047-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 16.5' LRU-OY L~-C>/ ~1 5· 2. .0'- 8. Property Designation: Æ~.c::>" 10. Field/Pools(s): Lewis River Unit ..Á>'- S?>eol LEWIS RIVER/Beluga, Tyonek t~lJIÞ/~ 2/~ tI~ $4.> >1JCJ~ z:Þ 11. PRESENT WELL CONDITION SUMMARY "AD ~'. ¡. . t(. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,480' . 9,480' ~ 4,582' 4,582' 5,900'; 7,650' 5,855' Casing Length Size MD TVD Burst Collapse Structural 48' 30" 48' 48' Conductor 363' 20" 363' 363' 1,530 psi 520 psi Surface 1,368' 13-3/8" 1,368' 1,368' 2,730 psi 1,130 psi Intermediate Production 8,147' 9-5/8" 8,147' 8,147' 6,870 psi 4,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2,802' to 5,764' 2,802' to 5,764' 1-1/4"; 2-3/8"; 2-7/8" L-80; N-80; N-80; 1,938'; 5,760'; 4,691'; Packers and SSSV Type: Too numerous. Please see attached. Packers and SSSV MD (ft): See attached. 12. Attachments: Description Summary of Proposal l:j 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development [] Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/7/2006 Oil 0 Gas [] Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Branden3urg .--.... Title Drilling Manager Signature ?~/ A ~Phone 907-276-7600 Date ~- L:? ._~ -ð Á COMMISSION USE ONLY i:./ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: l~{a - t 5 ~ Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ~OOO ~~l: K\"''''M-.\J>K~~~'~-\- ~OYDIf;; RBDMS 8Ft MAY () 8 2006 Subsequent Form Required: W '~MMISSIONER APPROVED BY Date: 5-g,oP Approved by: THE COMMISSION V -~ ~ S'.Z·ol. Form 10-403 Revised 07/2005 lug ack and recom lete Sub ï in Du Ii te OR!GINA~ p ~?~ e e Lewis River Unit LRU ~ ~J .Ç.z·o~ Plug back and recomplete ~ MIRU Slickline. Gauge tbg to fill tag depth @ 4582'. Chk/open Sldg Slve @ 3930'. POOH RD. ~ MIRU Eline. PVMU 2-7/8" CIBP. Set same @ 3900'. POOH. ~ PUMU 2-7/8" Cmt Ret wi poppet valve. Set same @ 2795'. POOH. RD. ~ MIRV Cementers. ./ ~ Mix/pump 80 bbls of G neat. Launch! bump wiper ball on ret @ 2795'. RD cementers. ~ wac for 24 hrs. ~ RU Slickline. RIH tag cmt in tbg. POOH. RD ~ RU Eline. RIH punch tbg @ 2780'. PUMU Cmt ret. Set same @ 2760'. RIH punch tbg @ 2145'. POOH. RD. ~ MI Spot CT Unit. Tumkeyed RU Mobe. Test CTC & BOPE ~ ~ Accept CT Unit. PUMU Stinger. RIH stab into retainer @ 2760'. Mixlpump 42 bbls ofG neat. PU above retainer CBU. ~ Jet well dry wi N2. POOH. Demobe CT. ~ RU Slickline. RIH wi temp survey tool to retainer to identify TOC. POOH. RD. ~ wac for (3) days. / ~ MIRV Eline. RIH perf Beluga 25-6 sand. POOH RD. ~ Turn well over to production. E..~~\ ~\'-.)M.!t"> ~'S~,' ~~,,~"\'\ \.. ~~,'\(:)t-> \ _.... \ ,.~ -\~(c E:...--0. <:>~'\.t"-~ \(~. (\ """'U \":>0'-""'" "~ t>e..~~ J.... ~ \.~\O--\-'\c" ~,~\~ \Ï\.~, þ ~ ~~~\C)(:. ¡;~1M S(...çOCo RKB= 16.5' LP 48' 94 H-40 Butt 363' 456sx 13-3/8" 54.5 K-55 943' 17-l/2" 1031sx 61 1368' P-ll 0 8141' S-95 7901' 9-5/8" N-80 6985' 12-114" 47 4502 N-80 8.681 4500 6.4 N-80 Butt SC 2.441 2-3/8" 4.6 N-80 Butt SC 1.995 1-l/4" 2.3 L-80 CS H dril 1.380 Fill tagged @ 4582' on 10/4/04 Cmt938!1'-9480' TD= 0' Max Hole Angle = LRU lA Current <II7U¡¡¡;< ÐV ÐIi:~All Nii ri~£)tll :L{;'Ul!th II)~ U{;'m 14,0' McEvov DuaLTubing Hanger, 7-7/8" .;K OlV! 1. 297' 2.5 2313 3.25 Otis "XXO" SSSV Landing Nipple . 3.85 (PIN 11 XXO 23100) 2. 206, 3.37 2.313 3.75 Otis "XA" Sldrr Slve 3. 2098 ]2.0 2.44 4.44 Otis Straight Slot Seal Assy wIll' ofsæ¡~- 13.81 3.88 8.30 Otis "VST" Production Pkr wI 7.46' SBE 4, 3883 12.0 2.44 4.12 Otis Straight SlotSea] Assy w/]I' of Seals 13.87 3.88 8.30 Otis "VST" Production Pkr wI 7.52' SBE 5. 3930 3.35 2.313 3.75 Otis "XA" Sldg Slve 6. 3934' 20'.]8',28', 2.44] 3.50 Carbide Blast Rings; , j~~4 -4V.?~ 4382' 34',19'.19' 409]' 4122',4187'-4247'4263'-4294' '" ,~, 7. 4646 3.34 2.313 3.75 Otis "XA" Sldg Slve 8, 4676 ]0.09 2.44 4.12 Otis Straight Slot Seal Assy wi 9' of Seals 14.48 3.88 8.30 Otis "VST" Production Pkr wI 8.11' SBE 9. 4691 0.70 1.94 3.52 Crossover" 2-7/8" BTC x 2-3/8" BTC 10. 4721 1.32 1.875 2.90 Otis "X" Profile Nipple 11. 5470 10.19 2.44 4.12 Otis Straight Slot Seal Assy wI 9' of Seals ]4.47 3.88 8.30 Otis "VST" ProductioIl Pkr wI 8.09' SBE 12. 5516 3.34 1.875 3.03 HES "XA" Sldg Slve 13. 5729 1.32 1.875 2.90 HES "X" Profile Nipple 14. 5760 0,76 1.94 6,05 WLEG DRAWN BY: SLT RKB= 16.5' LP Surf 48' Driven 94 H-40 Butt 19.124 Surf 363' 26" 13-3/8" 54.5 K-55 12.615 Surf 943' 17-112" 103Isx 61 12.515 943' 1368' P-IIO 7907 8147' 400sx S-95 8.681 6985 7907' CBL N-80 4502 6985' RaHy 4500' to 5568' 9-5/8" 47 4500 4502 12-1/4" N-80 8.681 Surf 4500 Tubin 2-7/8" 6.4 N-80 2-3/8" 4.6 N-80 1-114" 23 L-80 Cmt 9380'-9480' TD= Max Hole Angle = LRU lA Purposed 1 NO, O~plb L~m!:lb II} 00 lI~m 14.50' McEvov Dual TubinQ' Han""r, 2-7/8" x 2_7/8" SLRT 11" 5M 1. 297' 2.5 2.313 3.25 Otis "XXO" SSSV Landing Nipple 3,85 (PIN ¡¡ XXO 23100) 2. 2065 3.37 2.313 3.75 Otis "XA" Sldg Slve 3, 2098 12.0 2.44 4.44 Otis Straight Slot Seal Assy wi !! ' of Seals !3.8! 3,88 8.30 Otis "VST" Production Pkr wi 7.46' SBE 4, 3883 12.0 2.44 4.12 Otis Straight Slot Sea! Assy wi 1 l' of Seals 13.87 3.88 8.30 Otis "VST" Production Pkr wi 7,52' SBE 5. 3930 3.35 2.3 13 3.75 Otis "XA"Sldg Slve 6. 3934' 20',]8"28', 2.441 CarbideB!astRinb'$; 3934' 3965', :'YY 4\J¿O, 4382' 34',]9'.]9' 3,50 4091'-4122',4187'-4247'4263' 4294', "O~~, 'oo~, 7, 4646 3.34 2,3!3 ~ Ori> "XA" SId, sw" 8, 4676 10.09 2.44 4.1 Otis Straight Slot Sea! Assy wi 9' of Seals !4.48 3.88 8.3 Otis "VST" Production Pkr wi 8.1!' SBE 9. 469! 0.70 1.94 3.52 Crossover, 2-7/8" BTC x 2-3/8" BTC 10, 472! 1.32 1.875 2,90 Otis "X" PrQfi!e Nipple 11. 5470 1O.!9 2.44 4.12 Otis Straight Slot Seat Assy wi 9' of Seals !4.47 3.88 8.30 Otis "VST" Production Pkr wi 8.09' SBE !2. 5516 3.34 1.875 3.03 BES "XA" S!dg Stve 13. 5729 1.32 1.875 2.90 HES "X" Profile Nipp!e 14. 5760 0.76 1.94 6.05 WLEG DRAWN BY: SL T 01 1ID 00 V\I1!if~a:HttJkj) OOJI D<\IE , r e e increased to 1200 psi. After the second zone was perforated the tubing pressure dropped to 450 psi and the well bore filled partially with water. The operator was not able to get the well back on production when he completed the perforation operation. It is apparent that one of the first two zones, most likely the second one, was water prone and killed the well. The well is currently incapable of production due to water influx either from the perforations at 3850' to 3856' or 3800' to 3828' md. Had these zones not been perforated through tubing it may be possible to squeeze them without pulling the tubing. Now however it is infeasible to squeeze individual perforations, without pulling the tubing, and the only way to effectively seal off these perforations is to squeeze cement behind the tubing as the operator proposes. This action will effectively isolate all open perforations in the wellbore. The operator then plans to perforate a single interval that is shallower than all current perforations in an attempt to restore this well to production. This well is currently incapable of production and it is unlikely that any of the existing perforated intervals would, if the water prone zones are isolated, be capable of any significant production. Therefore, I believe that the operator's proposal for restoring production will not result in a significant loss of reserves and I recommend that Sundry Application306-l58 be approved. D.S. ROb~ May 5, 2006 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. - '~Date: ~>1~5 SCANNED JUN 1 6 2005 }~),;l~~~~\~;,j,;,'!:J(~~~f~i~~JI!~~~~~~fiN~t;Z:~t~~+W!, ii[~~~~¡~ tiil,~'i~&)[ !(,~~iæ' LRU1A, " 'PERFRECORD2.5HSDGUN 6SPFGA 51NCH 1.1106/20042650-3856 , ,,1, ,,1: 1'," . ". '" _.. ...... ..... ...~ ... .. . . .~.. n ", ~......~. .... ,~u....... ... . . u..j. ...~..... ... J _ ....._ .~ ........" .... ....... ... ..... ... u .... I 'L ~... ....... .... . . . ... .... ...... .. . "';" .. .. ...~....... . ~.. .... ... ,;. ~ u... .,~.. .... _. ;... .. .'. ..'... :.............. ~I.IID- LEWIS RIVER lA To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 Date: March 9, 2005 Debra Oudean G & G Technician UNOCALfla Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com / 7 S - d-(),:)' ) ) STATE OF ALASKA ALASKP t AND GAS CONSERVATION COMMISP'j RECEIVED. REPOR ,. F SUNDRY WELL OPERA'.. NS JAN 1 0 2005 I. Operations Abandon U Repair Well U Plug Perforations U Stimulate U ~th~r lJ c~mm¡ss¡on )erformed: Alter Casing 0 Pull TubingD Perforate New Pool D WaiverD 1\mBtQi.ts~ Cmu~. Change Approved Program 0 Ope rat. Shutdown D Perforate 121 Re-enter Suspended Wel~hOrage ~. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: ~ame: Development 121 Exploratory Q, . 75-05 L Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic 0 ServiceD 6. API Number: 50-283-20047 9. Well Name and Number: LRU A-1 10. Field/Pool(s): Lewis River FieldlBeluga, Tyonek r. KB Elevation (ft): 118' I. Property Designation: :ast Lewis River 11. Present Well Condition Summary: rotal Depth measured 9,480' feet true vertical 9,480' feet :ffective Depth measured 5,855' feet true vertical 5,855' feet ~asing Length Size MD Structural 48' 30" 48' Conductor 363' 20" 363' Surface 1,368' 13-3/8" 1,368' Intermediate 8,144' 9-5/8" 8,144' Production Liner Plugs (measured) BPs: 5,900', 7,650'; CPs: 8,000', 9,044', 9,380' Junk (measured) 5,855' TVD Burst Collapse 48' 363' 1,530 psi 520 psi 1,368' 2,730 psi 1,130 psi 8,147' 6,870 psi 4,760 psi SCANNED FEB 0 2 2005 'erioration depth: Measured depth: 2,790 to 7,730' True Vertical depth: 2,790 to 7,730' rubing: (size, grade, and measured depth) 2.875",2.375"; N-80, N-80; 4,691', 5,760' 'ackers and SSSV (type and measured depth) Otis VST Production Packer @ 2,098',3,883',4,676',5,470'; Baker XXO SSV @297' 12. Stimulation or cement squeeze summary: ntervals treated (measured): n/a RBDMS BFL FEB 0 rreatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 300 0 Produced water 15. Well Class after proposed work: Exploratory 0 Development 121 16. Well Status after proposed work: OilD Gas 121 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 80pies of Logs and Surveys Run Daily Report of Well Operations Service 0 x GINJ 0 WINJ 0 WDSPL D Sundry Number or N/A if C.O. Exempt: 304-391 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Signature 7-: / c,.6 c:;¡? Form 10-404 Revised 04/2004 / Title Drilling Manager Phone 907-276-7600 Date 12/16/2004 Submit Original Only RBDMS BFl FEB 0 1 2005 11/1/04 ) ) RU, loaded gun, and stabbed onto well. Could not get a pressure test. RD Schlumberger and removed tree flanges. Installed old tree cap and secured well with night cap. TP@ 800 psi. Perforating on hold. 11/6/04 RU. PJSM. PT to 2500 #. Very slow leak to 1750#, holding at 1750#. Opened masters. Swab holding. WIH with gun #1 (6'). No problem with gun falling. Tied in with RST 10/4/04. TP@ 100 psi. Perforated 3850-3856 (6 feet) 2.0" HSD PJ, 6spf. Logged up and POOH, no problems. WIH wI gun #2 (28') and CCL. Sat down at 3896'. Logged up and tied in wI first GR/CCL run. TP@ 1200 psi. Perforated 3800-3828 (28feet) 2.0" HSD PJ, 6spf. Logged up and POOH. TP@ 1100 psi. 11/7/04 Made up gun and pressure tested to 2700 # okay. PJSM. Greased all valves again. WIH wI gun #3 (7') and GR/CCL. TP@ 450 psi. Tied in wI RST 10/4/04. 1. Saw fluid level @ 850' 2. Sticky fluid wI weight loss on line, 1420-2080'. Line weight +1- 10 #. 3. 2080-3800, line weight steady at 110 #. . 4. Calc. pressure at perf depth of 3715' is 1682 psi. (Normal reservoir hydrostatic calculates 1634 psi). Perforated 3715-3722 (7 feet). 2.0" HSD PJ, 6spf. POOH. WIHwl gun #4 (7') and GR/CCL. Fluid level at 894'. TP@ 450 psi. Tied in wI RST 10/4/04. Perforated 3084-3091 (7 feet). 2.0" HSD PJ, 6spf. POOH. WIH wI gun #5 (6') and GR/CCL. Fluid level at 9351. TP@ 450 psi. Tied in. Perforated 2822-2888 (6 feet). 2.0" HSD PJ, 6 spf. POOH. WIH wI gun #6 (17') and GR/CCL. Fluid level at 975'. TP at 450+ psi. Perforated 2802-2819 (17 feet) 2.0" HSD PJ, 6spf. POOH. TP@ 500 psi (-). SDFN. LRU A-1 morning report summary, CONFIDENTAL: last revised 12/16/2004, Page 1 ') UNOCAL 30" @ 48' L 20", 9.4# @ 363' L 13-3/8" 61 and 54.5#K-55 @ 1,368'L ** Blast Ring intervals at 3,934 to 3,964'; 3,994 to 4,024'; 4,091 to 4,121'; 4,186 to 4,247'; 4,263 to 4,294'; 4,352 to 4,382' MIDDLE BELUGA LOWER BELUGA UPPER TYONEK Junk @ 5,855 Bridge Plug @ 5,900' Bridge Plug @ 7,650' Cement 8,000 to 8,176' 9-5/8",47# @ 8,144' Cement 9,044 to 9,144' Cement 9,380 to 9,480' ... A ""3 t ~4 6 - . 10 T,.~nical Schematic LewIs River 1-A Completed as of 1/10/90 last revised 10/25/04 - DED 2-718", 4.6# N~80 Butress, Surface to 4,691' ~ 1. Baker Sub Surface Safety Valve ~ 297' 2. Otis XA Sliding Sleeve @2 2,065' 3. Otis VST Production Packer ~ 2,098' * 4. Otis VST Production Packer @2 3,883' * 5. Otis XA Sliding Sleeve ~ 3,927' 6. Carbide Blast Rings with a 5' Overlap ** 7. Otis XA Sliding Sleeve @2 4,643' 8. Otis VST Production Packer (Q2 4,676'* XO to 2-3/8", 4.6# N-80 Butress @2 4,691' 9. Otis 2-3/8" X Nipple @ 4,721' 10. Otis VST Production Packer ~ 5,470' * 11. Otis XA Sliding Sleeve @ 5,515' 12. Otis 2-3/8" X Nipple (Q2 5,729' 13. Wireline Re-entry Guide @2 5,759' ~ ~ * Denotes drill pipe measurement A. Heater String 1-1/4" CS Hydril @ 1,956' 8 Perforation Record 2,790 to 2,792' Squeezed 2,802 to 2,819' 11/2004 2,804 to 2,812' Squeezed 2,822 to 2,888' 11/2004 ./ 2,830 to 2,832' . Squeezed 3,084 to 3,091' 11/2004 i , 3,084 to 3,094' "Squeezed 3,647 to 3,651' . Squeezed 3,715 to 3,722' 11/2004 3,715to 3,722' 11/2004 3,717 to 3,725' Squeezed 3,800 to 3,828' 11/2004 ,~ 3,850 to 3,856' 11/2004 3,948 to 3,958' Open 4,008 to 4,016 Open 4,096 to 4,116' Open 4,202 to 4,210' Open 4,227 to 4,233' Open 4,278 to 4,287' Open 4,360 to 4,369' Open 4,730 to 4,738' Squeezed 4,984 to 4,994' Squeezed 5,014 to 5,036' Squeezed 5,528 to 5,553' Open 5,576 to 5,600' Open 5,668 to 5,688' Open 5,707 to 5,715' Open 5,736 to 5,764' Open 6,097 to 6,102' Isolated 7,725 to 7,730' Isolated TD: 9,480' RKB: 118', 0 degrees inclination ) 30" @ 48' ¿ 20",9.4# @ 363' ¿ 13-3/8" 61 and 54.5# K-55 @ 1,368'¿ MIDDLE BELUGA LOWER BELUGA UPPER TYONEK Junk @ 5,855 Bridge Plug @ 5,900' Bridge Plug @ 7,650' Cement 8,000 to 8,176'L-": 9-5/8",47# @ 8,144' Cement 9,044 to 9,144' Cement 9,380 to 9,480' ) Technical Schematic Lewis River 1-A Completed as of 1/10/90 last revised 10/25/04 c DED 2-7/8",4.6# N-80 Butress, Surface to 4,691' ~ 1. Baker Sub Surface Safety Valve @ 297' 2. Otis XA Sliding Sleeve @ 2,065' 3. Otis VST Production Packer @ 2,098' * 4. Otis VST Production Packer ~ 3,883' * 5. Otis XA Sliding Sleeve ~ 3,927' 6. Carbide Blast Rings with a 5' Overlap ** 7. Otis XA Sliding Sleeve @ 4,643' 8. Otis VST Production Packer@ 4,676' * XO to 2-3/8",4.6# N-80 Butress @ 4,691' 9. Otis 2-3/8" X Nipple @ 4,721' 10. Otis VST Production Packer @ 5,470' * 11. Otis XA Sliding Sleeve @ 5,515' 12. Otis 2-3/8" X Nipple @ 5,729' 13. Wireline Re-entry Guide ~ 5,759' -- ~ A ~ 11!18 2 3 * Denotes drill pipe measurement . ** Blast Ring intervals at 3,934 to 3,964'; 3,994 to 4,024'; 4,091 to 4,121 '; 4,186 to 4,247'; 4,263 to 4,294'; 4,352 to 4,382' . A. Heater String 1-1/4" CS Hydril ~ 1,956' ~5 ¡ 6 - ...... 7 . Perforation Record "z H/°-4-2,790 to 2,792' Squeezed 2t¡oZ~ 8t~ I 2,804 to 2,812' Squeezed 2~Z.2" 28ßg ~or 2,830 to 2,832' Squeezed .3,084 to 3,094' Squeezed 10 30~A" ~H 3,647 to 3,651' Squeezed 3:+15'- 311211k(' 3,717 to 3,725' Squeezed 1'3,948 to 3,958' Open 12 3'ð~D-,~Sb 1-1'4,008 to 4,016 Open 8IJ 13 == J~óo -3~2ð Iifb4 4,096 to 4,116' Open 4,202 to 4,210' Open 4,227 to 4,233' Open 4,278 to 4,287' Open 4,360 to 4,369' Open 4,730 to 4,738' Squeezed 4,984 to 4,994' Squeezed 5,014 to 5,036' Squeezed 5,528 to 5,553' Open 5,576 to 5,600' Open 5,668 to 5,688' Open 5,707 to 5,715' Open 5,736 to 5,764' Open 6,097 to 6,102' Isolated 7,725 to 7,730' Isolated 8 c=:J i8 9 IB! 11 '~------"'n_~ . ----~~ TD: 9,480' RKB: 118', 0 degrees inclination ~ Œ rnJ ffS 00 AI,ASIiA OIL AND GAS CONSERVATION COMMISSION Tim Brandenburg Drilling Manager Union Oil Company of California P.o. Box 196247 Anchorage, Alaska 99519 Re: Lewis River LRU-A-1 Sundry Number: 304-391 Dear Mr. Brandenburg: ) FRANK H. MURKOWSK/, GOVERNOR 333 w. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal eommission decision to Superior Court unless rehearing has been requested. BY ORDER OF TW: COMMISSION DATED this~ day of October, 2004 Encl. SCANNEr) NO" 0 ~ 20(W - . '\ STATE OF ALASKA .... A ALASt\.A)IL AND GAS CONSERVATION COMMk >ON RE E Q~(06 Ço APPLICATION ~~~~2~.~8~RY APPROVAL OCT 2.~ 2004 cr~;-p Operational shutdown U Perforate ~t ~ ,., ¥yaiver U Annul~1r i;>ispos. U Plug Perforations 0 Stimulate t1s¡Ytr»JI~~1t~foR~. COinmBSSI06\her 0 Perforate New Pool 0 Re-enter suspendé~l~~r~ 4. Current Well Class: 5. Permit to Drill Number: Development 0 Exploratory 0 75-05 V Stratigraphic 0 Service 0 6. API Number: . 50-283-20047 / Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 118' 1. Type of Request: 8. Property Designation: East Lewis River 11. Total Depth MD (ft): 9,480' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 2,790 to 7,730 Packers and SSSV Type: Total Depth TVD (ft): 9,480' Length 48' 363' 1,368' 8,147' PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 5,855' 5,855' Size MD 30" 48' 20" 363' 13-3/8" 1,368' 9-5/8" 8,147' Suspend U Repair well 0 Pull Tubing 0 9. Well Name and Number: LRU-~ ~- \ 10. Field/Pools(s): Lewis River Field/Beluga, Tyonek Plugs (measured): 5,900 Junk (measured): 5,855' TVD 48' 363' 1,368' 8,147' Burst CoJlapse 1,530 psi 2,730 psi 6,870 psi 520 psi 1 ,130 psi 4,760 psi Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 2,790 to 7,730 2.875"; 2.375" N-80; N-80 Otis VST Production Packer (4); Baker XXO Packers and SSSV MD (ft): SSSV BOP Test 0 Date: Tubing MD (ft): 4,691'; 5,760' Packers: 2,098'; 3,883'; 4,676'; 5,470'; SSSV: 297' 12. Attachments: Description Summary of Proposal L:J Detailed Operations Program D BOP Sketch 0 14. Estimated Date for Commencing Operations: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim C. Brandenburg Title Drilling Manager Signature ~¡f ~ Phone 907-276-7600 Date " ð./ COMMISSION USE ONLY 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: 10/29/2004 Oil 0 Gas 0 WAG 0 GINJ 0 Abandoned WDSPL 0 0 0 Service 0 0 0 Plugged WINJ Contact Steve Tyler 263-7649 10/25/2004 ,Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30V - 3?J Plug Integrity 0 0 0 Mechanical Integrity Test Location Clearance Other: ßO ~ \ ~ (At-GCJ ~ ~ ( éIO ~~C- "d-S , d <6,\ OCT 2 9 BfL 16. Verbal Approval: OR\G\NAL "- BY ORDER OF THE COMMISSION Dare: su:~rPf COMMISSIONER INSTRUCTIONS ON REVERSE ) UNOCAL8 30" @ 48' L 20", 9.4# @ 363' L 13-3/8" 61 and 54.5# K-55 @ 1,368' L MIDDLE BELUGA LOWER BELUGA UPPER TYONEK Junk @ 5,855 Bridge Plug @ 5,900' Bridge Plug @ 7,650' --.. 3~W =I. . A* D. enotes drill pipe measurement =I Heater String 1-1/4" CS Hydril ~ 1,956' ~ 4 ~y,<¡s"'" Perforation Record 6 - 2,790 to 2,792' Squeezed ~ 2,804 to 2,812' Squeezed ')%1»....... 2,830 to 2,832' Squeezed --. 3,084 to 3,094' Squeezed 8 '-\lo t l, 3,647 to 3,651' Squeezed ~"'\;' 3,717 to 3,725' Squeezed 3,948 to 3,958' Open 4,008 to 4,016 Open 4,096 to 4,116' Open 4,202 to 4,210' Open 4,227 to 4,233' Open 4,278 to 4,287' Open 4,360 to 4,369' Open '-\5"~ 4,730 to 4,738' Squeezed 4,984 to 4,994' Squeezed 5,014 to 5,0361 Squeezed 5,528 to 5,553' Open 5,576 to 5,600' Open 5,668 to 5,688' Open 5,707 to 5,7151 Open 5,736 to 5,764' Open 6,097 to 6,102' Isolated 7,725 to 7,730' Isolated .... - A f Cement 8,000 to 8,176' 9-5/8", 47# @ 8,1441 Cement 9,044 to 9,144' ~~ Cement 9,380 to 9,480' 1 :khnical Schematic Lewis River 1-Ä Completed as of 1/10/90 last revised 10/25/04 - DED 2-7/8",4.6# N-80 Butress, Surface to 4,691' ~ 1. Baker Sub Surface Safety Valve ~ 297' 2. Otis XA Sliding Sleeve @ 2,065' 3. Otis VST Production Packer ~ 2,098' * 4. Otis VST Production Packer ~ 3,883' * 5. Otis XA Sliding Sleeve ~ 3,927' 6. Carbide Blast Rings with a 5' Overlap 7. Otis XA Sliding Sleeve ~ 4,6431 8. Otis VST Production Packer ~ 4,6761 * XO to 2-3/8", 4.6# N-80 Butress ~ 4,691' 9. Otis 2-3/8" X Nipple ~ 4,721' 10. Otis VST Production Packer @ 5,470' * 11. Otis XA Sliding Sleeve ~ 5,515' 12. Otis 2-3/8" X Nipple ~ 5,729' 13. Wireline Re-entry Guide ~ 5,759' ~ ~ 10 TD: 9,480' RKB: 118', 0 degrees inclination "",' ') ) LRU I-A Work Summary Perforate Lower Beluga Sands . MIRV Slickline. Tag fill. RIH wi dummy gun. RD Slickline. . MIRV Eline. RIH wi 2-l/8"guns (Power Spiral, 6spf). . Perf Lower Beluga sands (GR log to determine DIL perf depth). (perf) 4574'md to 4580'md (reopen previously squeezed perfs) 3715'md to 3722'md (reopen previously squeezed perfs) 3084'md to 3091 'md (perf) 2882'md to 2888'md (reopen sqz perfs + 9' new perfs) 2802'md to 2819'md . RD Eline. . Turn well over to production. DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVE JUNEAU, ALASKA 99687 http ://www.state.ak.us/dec/deh Telephone: (907) 465-5162 Fax: (907) 465-5362 Harry A. Eaton HES Manager Unocal Alaska 260 Cavi~ Street Kenai, Alaska 99611 ~' g i~-~ ~~'~m°r~°- ~i~io~ Reference: Issuance of Permanent Closur~Approval for Inactive Reserve Pi~ iocatedat Lewis River &-l, B-l, C~I, D-Vand Pretty Creek ~ 2 located on the west side of Cook Inlet ~ De~ Mr. Eaton: h~q/~-~ ~ _ ~ ~ ~ ~/~-~ The Alaska Dep~ment of Environment~ Conservation (ADEC) has completed review and public notice for ~anent closure approv~ for the above reference rese~e pits located in the Susitna ~ats State Game Refuge. The closure applications provided the required info~ation describing the histo~ of the rese~e pit(s), the present condition of the rese~e pits(s), results of any required water sampling and an assessment of the potential risks posed by the drilling waste to human health and the environment. At these locations, the reserve pits are backfilled and there is no exposed drilling waste. ADEC coordinated sever~ field inspections of the sites with the Alaska Dep~ment of Fish and Game and the Alaska Department of Natural Resources. Public notice requesting comments on the closure requests was published September 20 and 21, 2001 in the Anchorage Daily News and posted on the state web site September 21, 2001. No public comments objecting to closure approval were received in response to this public notice. ADEC has determined that the reserve pit at this site meets the closure requirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 (j), ADEC grants permanent closure approval to Unocal Alaska for the inactive-reserve pits at the following sites: /Unocal Alaska Mr. Harry A. Eaton October 23,2001 Page 2 of 2 Well Name Lewis River 1 (A-l) Lewis River B-I ~' Lewis River C-1 Lewis River D-1 ~' Pretty Creek #2 '~ API Number 50-283-20047-00 50-283-20052-00 50-283-20061-00 50-283-20068-00 50-283-20022-90 MTRS Sec. 02, TI4N, R9W, SM Sec. 10, TI4N, R9W, SM ' Sec. 35, T I5N, R9W, SM Sec. 35, TI5N, R9W, SM Sec. 33, TI4N, R9W, SM Landowner ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR Terms and Conditions. This permanent closure approval is stibject to the following terms and conditions: 1) In accOrdance with 18 AAC 60.440(1), the Department will require additional investigation, assessment, monitoring or remediation if n6w information regarding conditions at the reserve pit facilities indiCates that~'further ~ctions .are necessary to protect human health or the environment. ; ~ - ,:" . 2) The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. ClosUre for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriate land owner/manager. · j ' · Any person who disagrees with any portion of t~is decision may request an adjudicatory hearing in accordance with 18AAC 15.200-'310. The reqffest should'be mailed to.the Commissioner of the Department of Environmental Conservation, 555 Cordova Ave. Anchorage, AK 99501. If a hearing is nOt requested within thirty (30) days of. the date of this letter, the right of appeal is waived. If an adjudicatory hearing is requested and .granted, this decision remains in full effect during the adjudicatory prOcess. Sincerely, Heather Stockard Solid Waste Program Manager Heather Stockard@envircon.state.ak.us cc: ~ :Tom-M-aunder;~A OGC C, "~!b~b~:~fi~ Heebnerl ADNR, Anchorage Wayne Dolezal, ADF&G, Anchorage John Hammelman, Unocal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~:51ON O REPORT OF SUNDRY WELL OPERATION:¢ 16 1. Operations performed: Operation shutdown __ Stimulate Plugging __ Perforate Pull tubing _.~ Alter casing Repair well ~ Other Na of, O er for. . . ypeofWell: 2. n~n~.o~ ~1 Company of Cal~fornza (UNO~A~L~. Development _.~.x · ! Exploratory 3. Addr[~s,.sO Box 190247, Anch, Ak , 99519-02~7 Stratigraphic · ' ' I- Service / 6. D~m:~,~tion (DF or KB) Location of well at surface 1600' FWL, 1700' At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole FNL, Sec. 2, T14N, Rgw, S.M. 8. Wellnumber Lewis River 1-A 9. Permit number/approval number 75-5 / 9-973 10. APl number 50-- 283-20047 11. Field/Pool Lewis River/Unnamed feet 12. Present well condition sUmmary Total depth' measured true vertical 9,480 · feet Plugs (measured) 5900 ' Straight Hq~ 9380' , 7650', 8000', 9044' Effective depth: measured 5,855 ' feet true vertical Straight Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth Size 48' 30" 363' 20" 1368' 13-3/8" 8147' 9-5/8" measured See Attachment #1 true vertical Tubing (size, grade, and measured depth) Junk (measured) 5855' Cemented Driven 456 sx 1031 sx 1926 sx 2-7/8", 6.4#, N-80, Buttress 2-3/8", 4.6#, N-80, Buttress Measureddepth 48' 363' 1368' 8147' ~ueverticalde~h Same Same Same Same RECEIVED JAN 2 5 1990 Naska 0il & Gas Cone. ComaJssfOIT , ~chora~ ' Packersand SSSV (type and measured depth~aker SSSV @ 297', Otis VST Packers at 2098', ~67~', 5470' 13. Stimulation or cement squeeze summary 4730'-4738', 4984'-4994', 5014'-5036' Intervals treated (measured) 200 ft3 of Class "G" at 1400 psi Treatment description including volumes used and final pressure 3883', 14. RepreSentative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 1400 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas x Suspended Service 17. I here. l~ certify that the foreg¢ing is.t¢~ a0d correct.to the.best of my knowledge. ~'~-~- /~/~e~~-/ Environmental Analyst Signed Title Form 10-404 Rev 06/15/88 Date 1 / 22/90 SUBMIT IN DUPLICATE 30" ~ 48' 20-94// ~ 363' LEWIS RIVER WELL 1-A FIELD 2-7/8" 6.4~ N-80 BUTRESS 1. BAKER SUB SURFACE SAFETY VALVE AT 297' 2. OTIS XA SLIDING SLEEVE AT 2065' 3. OTIS VST PRODUCTION PACKER 2098' 4. OTIS VST PRODUCTION PACKER AT 3883' 5. OTIS XA SLIDING SLEEVE AT 3930' 6. CARBIDE BLAST RINGS WITH A 5' OVERLAP 7. OTIS XA SLIDING SLEEVE AT 4646' 8. OTIS VST PRODUCTION PACKER AT 4676' 9. 10. 11. 12. 13. XO TO 2 3/8" 4.6# N-80 BUTRESS AT 4691' OTIS 2 3/8" X NIPPLE AT 4721' OTIS VST PRODUCTION PACKER AT 5470' OTIS XA SLIDING SLEEVE AT 5515' OTIS 2 3/8" X NIPPLE AT 5729' WIRELINE REENTRY GUIDE AT 5760' A. HEATER STRING 1 1/4" CS HYDRIL AT 1938' 13-3/8" 61 & 54.5~ K-55 O 1368' MIDDLE BELUGA PERFORATION RECORD 2790 -2792 2804 -2812 2830 -2832 3084 -3094 3647 -3651 3717 -3725 SQZ D SQZ D SQZ D SQZ D SQZ D SQZ D 3948'-3958' OPEN 4008'-4016' OPEN 4096'-4116' OPEN 4202'-4210' OPEN 4227'-4233' OPEN 4278'-4287' OPEN 4360'-4369' OPEN ISOLATION DST ISOLATION DST DST DST PRODUCTION PRODUCTION DST PRODUCTION PRODUCTION PRODUCTION PRODUCTION LOWER B E LU GA ' · 4730'-4738' SQZ'D 4984'-4994' SQZ'D 5014'-5036' SQZ'D PRODUCTION PRODUCTION PRODUCTION UPPER ' TYONEK ' Junk ~) 5855' Bridge Plug ~ 5900' Bridge Plug ~ 7650' Crnt 8000'-8176' Cmt 9044'-9144, Cmt 9380'-9480' 9-5/8" 47# {~ 8147' T.D, O 9480' //////////// 10 5528'-5553' OPEN 5576'-5600' OPEN 5668'-5688' OPEN 5707'-5715' OPEN 5736'-5764' OPEN PRODUCTION DST PRODUCTION DST FRAC PRODUCTION 6097'-6102' OPEN 7725'-7730' OPEN DST ISOLATED ,JAN 2 5 1990 alas Gas Con . commi si.Qn TIGHT SPOT AT 5673', IT WILL DRIFT A 6-1/4" BIT. GRB 1-10-90 LEASE LEWIS RIVER UNOCAl RILLING RECORD ~' AI~ASKA REGION PAGE NO. 1 of WELL NO. 1-A FIELD LEWIS RIVER DATE E.T.D. 11/10/89 5650' CTM 11/11/89 5708' CTM 11/12/89 5708' CTM 11/15/89 5708' CTM 11/16/89 5708' CTM 12/11/89 12/12/89 5708' CTM 12/13/89 5708' CTM 12/14/89 5708' CTM DETAILS OF OPERATION,. DESCRIPTIONS & RESULTS Commenced operating with coiled tubing at 0700 hrs. Pressuretested BOPE to 4000 psi RIH (short string) with 1-1/4" coiled tubing and a 1.75" wash nozzle. Tagged hard fill at 347'. Washed fill to 382' while circulating 77 PCF CaCl2 @ 1 bbl/min & 4000 psi. RIH lightly tagged the downhole choke at 3904' CTM. Circulated bottoms up and POOH. Rigged up on the long string. Pressure tested BOPE to 3000 psi. RIH with 1.75" wash nozzle circulating 77 PCF CaC1z @ 1/4 bbl/min and 900 psi washed to tubing tail @ 5556'. Tagged fill at 5650' (CTM). Commenced operations at 0700 hrs. Pulled coiled tubing to 5356' and circulated foam until we had full returns. RIH making foam at 1/4 bbl/min. Washed to 5723' CTM. Unable to wash through. Circulated N2 until the well was dry. POOH. The surface "zero" was off by 15' indicating that hard fill might have been at 5708'. Suspended operations. No frac sand was recovered only "flour" sand. Rigged up wireline on the short string. Pulled the downhole choke at 3904'. Set a "BX" plug at 3904'. Set equalizing prong. Opened the sliding sleeve at 3872'. Attempted to circulate #1 diesel down the short string and up the annulus. No returns. Attempted to circulate 50 bbls of $1 diesel, neg. Suspended operations. MIRU. MIRU. Accepted Grace Rig #158 at 1800 hrs. Built 81 PCF CaClz brine. Pumped a 100 bbl sized salt kill pill against the Upper Tyonek with no pressure increase. The formation held 950 psi falling off to 900 psi in 30 min. Bled gas and filled the tubing at intervals. The well died. RIH and opened the "XO" sliding sleeve at 5071'. POOH. Bullheaded a 40 bbl kill pill to the lower Beluga with no pressure increase. The formation held 925 psi for 30 minutes. Bled gas off and filled the tubing at intervals. The well died. RIH and opened the "XO" sleeve at 4421'. Bullheaded a 100 bbl kill pill against the Middle Beluga with no pressure increase. The formation held 950 Psi. Bled the well off intermittently until dead. RIH and set an Otis 2-7/8" tubing plug at 100' in both the L.S. and the S.S. Removed the tree. Installed cameron BPV profiles. Installed BOPE. UNOCA 3RILLING RECORD A~ASKAREGION PAGE NO. 3 of LEASE LEWIS RIVER WELL NO. 1-A FIELD LEWIS RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 12/21/89 12/22/89 12/23/89 12/24/89 12/25/89 12/26/89 5626' 5796' 5796' .. 5796' 5198' 5198' RIH with an 8-1/2" string mill which was 1/16" out of gauge. Dressed the perforations to the fish at 5041'. Circulated bottoms up. No gas returns. POOH. RIH with a 7-5/8" guide and an overshot. Engaged the fish at 5041'. Released the packer. Circulated out gas. POOH with packer #3. RIH with an 8-1/2" bit and a 9-5/8" casing scraper with jars. Continued RIH with the bit and scrapers. Saw drag in the perfs from 4096' to 4110'. Saw tight spot at 5591'. Tagged fill at 5626'. Washed fill to 5648'. Rotated to clean out from 5648' to 5673'. Would not clean out any further. Circulated bottoms up, sand did not appear to be frac sand. POOH. RIH with a 6-1/8" bit and 9-4 3/4" collars. RIH and tagged fill at 5675'. Rotated and washed fill to 5796'. Continued to circulate. Pumped a hi-vis pill. POOH. Picked up mill #3. RIH and dressed the perfs from 4060'-4131' with an 8-1/2" tapered mill. Tight spot was no longer visible. POOH. RIH with 4-1/2" 37 gm 4 SPF tubing conveyed guns. Located guns with wireline. Set the packer at 5494'. Pressure tested the surface manifold and lines to 3000 psi, OK. Opened the tool and displaced with nitrogen. Bled the surface pressure off to give a mid-perf pressure of 1875 psi. Dropped the bar and perforated the Upper Tyonek: 5528'-5553', 5576'-5600', 5668'5688', 5707'-5715', 5736'-5749', 5752'-5762'. Performed a test as per the test sheet. Flared a total of 332,000 SCF. Closed the tool and filled the drill pipe with 81 PCF brine. Bullhead 30 bbls kill pill to perfs. Held 900 psi. Released packer and circ out gas. POH. Laying down tools and guns. RIH and set 9-5/8" EZ drill retainer at 5198'. POOH. RIH with 4-1/2" 37 gm 4 SPF tubing conveyed guns. Rigged up the test manifold. Positioned guns with a GR log and a radioactive sub. Tested the surface equipment to 3000 psi with nitrogen, OK. Displaced the drill pipe with nitrogen and monitored returns leaving 150' of fluid above the firing head. Set the packer at 4704' with the tail at 5039' Bled the nitrogen pressure down to 1390 psi. Dropped the bar and fired the guns. Perforated 4730'-4738', 4984'-4994', 5014'-5036'. Fluid level rose from 4528' to 962' in 1-1/2" hrs. No gas to surface. Released the packer and circulated bottoms up. Rigged down the surface equipment. POOH with the guns. UNOCA. ~RILLING RECORD '~ AIiASKA REGION PAGE NO. 4 of LEASE LEWIS RIVER WELL NO. 1-A FIELD LEWIS RIVER DATE. E]T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 12/27/89 12/28/89 12/29/89 12/30/89 12/31/89 1/01/90 4700' 4700' 4700' 5855' 5855' 5855' Continued to POOH with the guns. RIH and set an EZSV at 4700'. Rigged up the squeeze manifold and lines. Tested the drill pipe to 3000 psi and then tested the surface lines to 3000 psi, OK. Broke down the lower Beluga at 1750 psi with 2-1/2" BPM. Continued to pump into the formation at 1975 psi. Shut the pumps off and the pressure bled to 1000 psi. Batch mixed 200 cuft of Class "G" cement with 0.6% FL-10 and i gal/100 sx FPGL, mixed to 15.8 PPG. Final squeeze rate of 1 BPM @ 1400 psi. Cement was in place at 0808 hrs. Reversed out 1 sack of cement. POOH. RIH with 4-1/2" 37 gm 4 SPF tubing conveyed guns. Positioned the guns with a GR correlation. Set the packer at 3919' and the tail at 4370'. Tested all the surface equip to 3000 psi with nitrogen, OK. Displaced the drill pipe with nitrogen. Set the packer at 3919'. Shot a fluid level to verify that 150' of fluid was above the firing head. Bled the nitrogen to give a 30% drawdown. Dropped the bar and fired the gl/ns. Perforated 3948'-3958', 4008'-4016', 4096'-4116', 4202'-4210', 4227'-4233', 4278'-4287', 4360'-4369'. Tested the well as per the test sheet. Tested well from 0030 hfs to 0830 hrs. Shut in for a 1 hr buildup. Bullheaded a 60 bbl sized salt pill followed by 53 bbls of 81 pcf brine. Released the packer and circulated the gas out. POOH with guns. Continued to POOH with the tubing conveyed guns. With 1 stand of drill pipe in hole the well began to flow. Installed the safety valve and closed the.annular preventer. DP pressure built to 45 psi. Circulated down the drill pipe taking returns through the choke. Cleared the gas bubble which had apparently been trapped under the packer. Continued to POOH with the guns. RIH with an 8-1/2" bit and drilled on the retainer at 4700 for 7 hrs. POOH. RIH with a new 8-1/2" bit. Drilled on retainer at 4700'. Continued to drill on the retainer at 4700' Drilled hard cement for 12' and then some stringers. Drilled the retainer at 5198'. Chased junk to 5674'. Circulated and POOH. RIH with a 4-3/4" mill and chased junk to 5829'. Cleaned out fill to 5855'. POOH. Continued to POOH with 4-3/4" mill. RIH with an 8-1/2" bit and 9-5/8" casing scraper to 5660'. POOH. RIH with the #1 VST packer assembly and set it at 5470' with the 2-3/8" tail at 5760'. POOH. RIH with packer assembly #2. Continued to RIH with packer assembly #2. Stabbed into Packer #1 and set the #2 VST packer at 4676'. POOH. Made up 2-7/8" tail with carbide blast rings. RIH and stabbed into packer #2 and set the #3 VST packer at 3883'. POOH. LEASE LEWIS RIVER UNoC~.~ILLING RECORD ALASKA REGION PAGE NO. 5 of WELL NO. 1-A FIELD LEWIS RIVER DATE E.T.D. 1/02/90 5855' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS RIH with packer assembly $4. Stabbed into seal bore of packer $3. Tail at 3893'. Packer $4 set at 2098'. Test backside to 1500 psi-OK. POH laying down DP. Ran 57 jts (1939') of 1-1/4" CS Hydril heater string and 69 jts 2-7/8" butt production tubing. Stabbed into packer $4 seal bore. Spaced out and installed both tubing hangers. 1/03/90 5855' 1/04/90 5855' Landed both tbg strings in tbg spool 14.5' below K.B. ND BOPE. NU tree. Test annulus to 1500 psi-OK. Pulled BPV's. Rigged up wireline on production tbg. Pulled SSSV from 297'. Shifted XA's at 4643' and 2068' open. Pumped N2 down production string to 1015 psi or ~ 1900' equivalent fluid displacement. Shift XA at 2068' closed. Reset SSSV at 297'. · Rigged down wireline. Displaced heater string and annulus with 5174 gal diesel. Installed BPV's in production and heater strings. Cleaned pits. Released rig at 0800 hfs 1/4/90. RECEIVED 3AN 2 5 ].990 ~JasJ(a .OJJ & Gas Cons. Commission "~ ~chora~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION U APPLICATION FOR SUNDRY APPROVALS IG 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well m Alter casing __ Repair well __ Plugging m Time extension __ Stimulate ~ Change approved program ~ Pull tubing ~ Variance __ Perforate ~ Other 2. Name of Operator ! 5. Type of Well: Union Oil Company of California (UNOCAL) Developmentx ! Exploratory 3. Addr ,J. Stratigraphic ~.O. BOX 190247, Anch, Ak., 99519-021~7 Service 4. Location of well at surface 1600' FWL, 1700' At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole FNL Sec. 2, T14N, R9W, SM 6. Datum elevation (DF or KB) 7. Unit or P. roperLy name Lewis River 8. Well number Le;:'i_~ River 9. Permit number 75-5 10. APl number 50-- 283-20047 11. Field/Pool Lewis River/Unnamed feet 12. Present well condition summary Total depth: meaS'ured true vertical 9480' feet Straigh~e~ole Plugs(measured) 9380', 9044', 8000', 5900' 7650' Effective depth: measured true vertical 5855 · feet Junk(measured) 5855' Straight~ee~ole Casing Structural Length Size Cemented Measured depth True vertical depth Conductor Surface Intermediate Production Liner Perforation depth: measured 48' 30" Driven 48' Same 363' 20" 456 sx 363' Same 1,368' 13-3/8" 1031 sx 1,368' Same 8,147' 9-5/8" 1926 sx 8,147' Same true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments See attachment No. 1 RECEIVED DEC ! 21 9 Naslm 011 & Gas Cons. CommlssioD chorage 2-7/8", 6.4#, N-80 Buttress Baker "A-5" @ 3894', Baker "FH" 2 4433', Baker "FH @ 5~79' Description summary of proposal ~__ Detailed operations program __ BOP sketch x_..._ 14. Estimated date for commencing operation December 13, 1989 16. If proposal was verbally approved Mike Minder Name of approver 12/11/89 Date approved 15. Status of well classification as: Oil m Gas ~ Suspended __ Service 17. I hereby certify that the ~..~oing~s true an~cor~t to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORiGiNAL SIGNED LONNIE C. SMiT~ A,t~pro,~ed OOg¥ Re~mod ~, Gommissioner IApproval No. ~'--/~¢~'~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE LEWIS RIVER WELL 1-A CHANGE IN BOP EQUIPMENT Due to spacing limitations between Grace rig 158 and the casing head of Lewis River well i-A, Unocal is unable to install the complete BOPE stack as indicated in our original Application for Sundry Approvals dated 11/6/89. We wish to down grade our BOP from a 5000 psi rating to a 3000 psi rating by removing the single gate. The new proposed stack is shown in the attached schematic. Our Reservoir Department has double checked our maximum anticipated shut-in pressure from historical pressure test data and believe it to be approximately 2650 psi. This is within the range of a 3000 psi rated stack and we therefore anticipate no problems with the change. Ail BOPE tests and test notifications will be as per current regulations. There are no changes to the workover procedure. RECEIVED DEC 1 21989 Alaska Oil & Gas Cons. commis$iO, tt Anchorage LEWIS gIVER . 13 5/8" x $000[ Shaffer _/ 13 5/8" x 50001 Shaffer Double Gate ~-! $ooot ~j I jMud Cross! Grace Drilling Company Pig t158 Proposed B.O.P. Stack STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ APPLICATION FOR SUNDRY APPROVALJJ % \ ru 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well ~' ' Change approved program __ Pull tubing x..E._ Variance __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ~ Perforate x Other 2. Name of Operator ~ 5. Type of Well: Union Oil Company of California (UNOCAL) Development x_~... ,,! Exploratory 3. Address J Stratigraphic P.O. Box 190247, Anch, Ak., 99519-0147 Service 4. Location of well at surface 1600' FWL, 1700' At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole FNL Sec. 2, T14N, R9W, SM 6. Datum elevation (DF or KB) feet 7. Unit or Property name ~.ew~ River 8. Well number 9. Permit number I .' 75-5 10. APl number 50-- 283-20047 11. Field/Pool Lewis River/Unnamed 12. Present well condition summary Total depth: measured true vertical 9480' feet Plugs(measured) Straigh~eflole 9380', 9044', 5900' 8000' 7650' ! Effective depth: measured true vertical Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: Length measured 5 8 5 5' feet Junk (measured) StraighJ~e~ole true vertical Size Cemented 48' 30" Driven 363' 20" 456 sx 1,368' 13-3/8" 1031 sx 8,147' 9-5/8" 1926 sx See attachment No. 1 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments 2-7/8" 6 4# , · · Baker "A-5" @ 5079' 5855' Measured depth True vertical depth 48 ' Same 363 ' Same 1,368' Same 8,147 ' Same RECEIVED ,NOV o 6 ~:'~J~,$ka 0il & Gas Cons. Commissio~ ~ gnchora~ N-80 3894', Ba~e~ "~H" 2 4433', Ba~e~ Description summary of proposal __ Detailed operations program ~ BOP sketch .~_ 14. Estimated date for commencing operation ~ 15. Status of well classification as: Novembe~ ~ 6 ~ 1989 1 16. If proposal was verbally approved Oil ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and c.orrect to the best of my knowledge. Signed 'r~o~'~/o~bC'e;~'~? Title Environmental Engineer FOR COMMISSION USE ONLY Gas x' Suspended __ Date 11 / 6/89 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test ~ Approved by order of the Commission Form 10-403 Rev 06/15~88 Subsequent form required 10- ~ O ~ -~e6 009~ Original Slgned By David W. Johnston ~ Commissioner J ApprovalNo. ~;/. ¢ 7 ~- Date //.--/.. ---~? SUBMIT IN TRIPLICATE I · · · · · · · · · 10. 11. 12. 13. 14. 15. LEWIS RIVER 1-A WORKOVER PROCEDURE MIRU Coiled tubing unit (1-1/4")· Test BOPE to 5000 psi. Clean out fill to ETD @ 5855'. Rig down coiled tubing unit. MIRU. Drilling rig. Kill well. Set BPV's, ND tree, NU and test BOPE. Recover existing dual completion: S.S. Tail at 3,908' L.S. Tail at 5,556' Dual Packer at 3,893' Single Packer at 4,433' Single Packer at 5,079' Make bit and scraper run (9-5/8") to 5,900' PBTD. Run Caliper, CBL, and a cased hole neutron log. Perform DST work and squeeze work as necessary. Clean out wellbore to 5,900' PBTD. Test squeezes as necessary. Resqueeze if necessary. Perforate as directed. Footage dependent on DST analysis. Estimated maximum footage = 148'. Run dual 2-7/8" completion with heater string. ND BOPE. NU and test tree. Release Rig. LEWIS RIVER 1-A PERFORATION RECORD 8/11/75 8/12/75 8/10/75 8/08/75 8/04/75 8/04/75 8/27/75 8/01/75 8/27/75 8/27/75 8/27/75 7/29/75 8/27/75 8/27/75 8/26/75 8/26/75 7/26/75 7/25/75 8/27/75 7/22/75 7/22/75 7/22/75 7/18/75 7/17/75 7/13/75 2790'-2792' 2804'-2812' 2830'-2832' 3084'-3094' 3647'-3651' 3717'-3725' 3948'-3958' 4096'-4116' 4202'-4210' 4278'-4287' 4360'-4364' 4364'-4369' 4730'-4738' 4984'-4994' 5014'-5020' 5026'-5036' 5535'-5545' 5576'-5586' 5586'-5600' 5675'-5685' 5744'-5752' 5757'-5764' 5707'-5715' 6097'-6102' 7725'-7730' SQZ' SQZ' SQZ' SQZ' SQZ' SQZ' OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN D D D D D D ISOLATION DST ISOLATION DST DST DST PRODUCTION DST PRODUCTION PRODUCTION PRODUCTION DST PRODUCTION PRODUCTION PRODUCTION PRODUCTION DST DST PRODUCTION DST FRAC DST FRAC DST FRAC DST FRAC DST ISOLATED DST ISOLATED MB MB MB MB MB MB LB LB LB LB UT UT UT UT UT UT UT 2/ft 4?ft 2/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft 4/ft MB = MIDDLE BELUGA LB = LOWER BELUGA UT = UPPER TYONEK 2" KILL LINE WiTH (2) 2" 5U VALVES i d; :'j; KILL LINE FROM MUD PMP IBELL I NIPPLE ~ 13 5/8" 5000 psi ANNULAR III II II III I II I I PIPE RAMS BLIND RAMS ! FLOWLINE 13-5/8" 5M FLANGE DOUBLE GATE 5M L_..] 13-5/8" 5M FLANGE , .I3" CHOKE LINE WITH ONE REMOTE AND ONE MANUAL 3" 5M VALVE CONNECTED TO CHOKE MANIFOLD PIPE RAMS · !,, '1 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M DCB SPOOL [ I. 13-5/8" BOPE 5M STACK WEST SIDE OPERATIONS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL,).. DRAWN: GRB SCALE: NONE DATE: IO'N 11'N89 CITIES SERVICE COMPANY SUITE 420 1016 WEST SIXTH AVENUE ANCHORAGE, ALASKA 99501 June 14, 1984. (907) 272-944! Mr. C. V. Chatterton; ~sSioner' Alaska O il'and Gas Conservation Cc~misSion 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Chat: Enclosed please find-for your approval Sundry Notices for the Cities Service Lewis~ River i~ar~ C-1 Wells. Our plans are to ~ce production from these two wells this' fall. If additional information is l required please let me know.· Sincerely, Reginald W. EtkinS Regional Land Mgr. - Alaska RE:mq Attachments RECEIVED JUN ! 5 Alaska Oil & Gas Cons. commission Anchorage ALASKa, /ILAND GAS CONSERVATION C ,vlMISSION __ _ SUNDRY NOTICES AND REPORTS ON WEL. 1. DRILLING WELL [] COMPLETED WELL I~ ~. Name of Operator 7. P,rmi, No. Cities Service Oil and Gas Corporation ' 75-5 1016 West 6th Avenue, Suite 420, Anchorage, Alaska 99501 50-283-20047 1600: FWL and 1700' FNL, Section 2, T. 14N/R. 9W, SM Lewis River x= 351,875 y= 2,681,050 11. Fiel~l and Pool I Unnamed 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 118' Kelly bushing ADL-58801 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: · (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] '- Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment r-I Repair Well [] Change Plans [] Repairs Made [] Other [] ' Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We propose to do the following work during the month of August, 1984: 1. Move in wireline unit. 2. .Pull tubing plugs. 3. Commence gas production. RECEIVED JUN 1 5 1984 Alaska 0ii & Gas Cons. Commission Anchorage 14. I hereby certify that the fore~+~g, is true and correct to the best of my knowledge. s ,g n ed'~ ~>~,~. }'~ ~.k~.~{~J~-~ Tide En~ineerin~ Manager Io~ fOr Commission uso Condi~o~f ~proval, if ang: Approved by Approved Copy .Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND ~. S CONSERVATION COMMISSION Boyle H. Hamilton Chairman Thru: Lonnie C. Smith ~-~ Commissioner August 11, 1981' Harold R. Hawkins Petroleum InspeCtor Location Clean up Inspection Cities Services Oil Co. Lewis River No. 1 Location 1600' FWL 1700' FNL Sec 2, T14N, R9W, SM August__ .2,_ 198! I left Anchorage at 11:00 a.m. by Troy Air service ~o Beluga River, arriving at 11:30 a.m. and at the Cities Service camp at 12:30 p.m. I inspected' the location clean up on Lewis River No. 1, at 1~00 p.m. Pictures (attached). I filled out an A.O.G.C.C. report (attached). In summary: The Lewis River No. 1 location is cleaned up adequately. ALASKA OIL.AND GAS CONSERVATION COMbiISSION ' SURFACE ABANDONMENT REPORT 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator _ ~-_I~/L~j ~ _~.~w 7~-~ Date Downhole Surface Location of Well Permit No. /J~-f) Ft. F!ztfL, / 7~'~ Ft. F/~/ L, AP1 No. 50- Sec. ~ , T_~_ ~, R~ ~b/, ,~ X. Unit' or Lease Name ' Wel 1 No. Field & Pool 20 AAC 25.120: WELL ABANDONMENT b~RKER: ( ~fT~A & of/~-~.) Dia. Steel Post (4"Min.) - , Length (10' Min.) Height Above Final Grade Level (4' Min.) Top of Marker Pipe Closed with: Cement..Plug Set: On Well Head , On Cutoff Casing Distance Below Final Grade Level Side Outlets: All Valves and Nipples Removed All Openings 'Closed , With Blinds INFORMATION BEADWELDED DIRECTELY TO MARKER POST: (List Where Different from File Informatio¢) Operator Well Number Ft. F Screw Cap , In Concrete Plug Ft. in. Welds , With Cement Unit or Lease Name , Surface Location of Well: L, Ft., F L, Sec , Other 20 AAC 25.170: LOCATION CLEAN-UP PITS: ~, Filled In 01'~., Liners Removed or Buried " Debris Removed ~ SURFACE OF PAD AND/OR LOC~ION: ~.~, Rough , Smooth p/, ~contoured~ ~ Fla~t , Compacted ., Other CLEAN UP OF ~AD AND/OR LOCATION: Clean f./, Pipe Scrap , Iron Scrap Paper , Other , Wood ~ , Mud , Cement SURROUNDINGA~EA: ,/ - Wooded ~z, Brush f/, Tundra Sand , Other , Gravel CONDITION SJ~RROUNDING AREA: Clean pz , Trash from Site Other · Trees and/or Brush from Clearing. Site ACCESS ROAD: ~, Dirt , Gravel Ice , Other CONDITION ACC~ESS ROAD AND SURROUNDINGJ Clean ~,/, Rough , Smooth 6>~, Trash from Operations , Trees and/or Brush fr-----~m Clearing Road , Spoil from Clearing Road Other REMAINING TO BE DONE: .z~Y'~ /./~- /~z~ /~ ~OoP x-O~zjrzo~ RECOMMEN~' APPROVAL OF AB~DO~ENT: Yes ~, No Final Inspections7. ~ ~'~.,' L',- -~:~ 05126181 ' DATE ~'- A -- ~" / 7'I 0 v ' ,i -WA~N R. HICKS Engineer Western Region 02..801B ~r STATE of ALASKA TO: FROM: sUBJECT: ~ef, ~~s ~on ~s ~v~ l-A, ~1o~ ~ a let~ ~ Cites ~ice Oil ~y r~est~ ~L 58801 ~ ~t ~ a ~ r~al~ ~y~ s~t~. l~e ~~ ~~ ~s ~11 is ~le of p~~~ g~ ~nUUes. S~e a r~l m~t is due ~ 1, 1975, CITIES SERVICE OIL COMPANY October 16, 1975 State of Alaska Department of Natural Resour.ces Oil and Gas Conservation Commission ~001 Porcupine Drive Anchorage, Alaska 99504 ATTN: Mr. Hoyle H. Hamilton Chief Petroleum Engineer 900 Colorado State Bank Building 1600 Broadway Denver, Colorado 80202 Telephone: 303-892-0263 RE: Lewis River No. 1 ~ Sec. 2-T14N-R9W Manatuniska Susitna, Alaska Dear Sir: Enclosed please find State of Alaska Form G-l, Open Flow Potential Report which Mr. W. Randolph Hicks stated we would send to complete the requirements concerning the completion of the above mentioned well. If there are further requirements, or should you have any questions or comments concerning the completion of this well, please do not hesitate to contact this office, or Mr. Hicks in Anchorage at 272-9441. Sincerely, Elizabeth Ann Allen Secretary Production Department EAA/s Enclosures Form No, G-1 REV to-69 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT MulL~-POIXT TEST Test Initial F~ Annual O Special Unnamed SUBMIT IN DUPLICATE Test Date No. i Field Operator Cities Service 0il Company ('ourity . [ Location Manatun±s Ica -I Sec. 1600' FWL 1700' FNL 2-T14N-R9W, SM Reservoir Lease Lewis River Completion Date 9/3/75 Total Depth T/Pay ] Producing 9480' 56'I '~t~J'J18-4364' Producing Thru Reservoir Wellhead TBG. ! CSG. Temperature Temperature X 89 'r 55 "F CSG. Slze 9-5/8" TBG. Size [ Y/t/Ft. O.D. 2-7/8" 6.5 2. 875 Pipeline Connectlo~ Non~ Multiple Completion (Dual or Triple) Dual (Report for Upper Zone) _ ~Vt/Ft. 47 I.D. Set @ 8. 681 8147 GasGravity [ Av,;?r0d. ] (Separator) Length . 555 3887 2157 Set @ 3905 Type Taps Flange Type production from each zone I.mo 2. 441 Gas-Liquid Hydrocarbon [ Gravity of Ratio MCF per Bbl. ] Liquid (Apt) OBSERVED DATA Flow Data - ' ' Casing Flowing Time (Prover) (Choke) Press. Diff. Tubing No. of Flow (Line) (Orifice) h Press. Press. Temp. Hours! Size Size psig w psig pstg *F ,, ~...~ 2.0 4. 026" 2.0 150 22 1 61 5 74 a. 2.0 ) " " 200 30 1495 F ~._75~, " " 240 35 1 265 ,. ) -1.25 ) " " 335 48.~ ~030 87 ?LOV~r CALCULATIONS ' Flow Temp. Gravity Compress. Coeffi- ___, /h - Factor Factor Factor Rate of Flow NO. cient P Pressure F F F Q MCF/D (24 Hr.)~/"w m psia t g pv · , !.. 26.236 60.19 14.55 ,987 1.040 1.0 169'~ .. " 80.25 " · 980 " " 2146 2. ;' 94.41 " .979 '" " 2522 _ 3. ...... ' ' 130 2'9 " 975 " " 3466 PRESSURE CALCULATIONS Pf2 Ps2 P 1 , p f Cal. w c BHP -,~ 2o,~ p 2 P~ -- , P Cl)sla) ...... S xv W P c 2037 apl 4,149,369 .... '1'801 : 4 m - 3,_243,60t - 905.768 i670 $ , 2,7818,9.00 1.360.469 , i~l~ ..... 12 2;010,724 [2_. 138: 645 1172 28 1~373,58412 ,77.~ 785 ,, Absolute Potentiai] n 4553 ~Cr/D 0. 679 · Region Engineer. Cities Service 0il CERTIFICATE: I, the undersigned, state that I am th~,-- , o! me - manager (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein ar~, true, correct and complete to St~l/re INSTRUCTIONS This form is lo be used for reporting multi-point back pressure tests crr~gas wells in Alaska, except those on which special orders are applicable. ' · The log log paper used for plotting the back pressure curve shall be of at least three inch cycles. NOMENCLATURE --__Actual rate of flow at end of flow period at W.H. working pressure (Pw). MCF/da. ~ 14.65 psia and 60OF. P _-=72 hour wellhead shut-in casing (or tubing) pressure whichever is greater, psia C St:~tic welihead working pressure as determined at the end of flow period. (Casing if flowing thru tubing, tubing if flowing thru casing), psta Pt : Fl-)wing wellhead pressure (tubing if flowing through tubing, casing if flowing through casing.) psla --._-Meter pressure, psla Diftorential meter pressure, inches water · r, (;ravity correction factor F :.::Flowing temperature correction factor t F = Supercompressability factor pv n --Slope of back pressure curve GL _-~G times average producing length of flow string mix Note: If P cannot be taken because of manner of completion or condition of well, then P YV W adding the pressure drop due to friction within the flow string to P . t must be calculated by -S F Q and l-e are factors utilized in calculating the pressure drop due to friction. c Form No. G-1 REV 10-69 STATE OF ALASKA OIL AND GAS CONSERVATION CO/V~I~EE GAS WELL OPEN FLOW POTENTIAL TEST REPORT Mult~-POI.~T TEST Test Initial r~ Annual O Special SUBMIT IN DUPLICATE Field [ Reservoir Unnamed Operator I Lease Cities Service 0il Company Lewis River M~/kVunis ka Location Sec. 2-T~N-R9W SM, 1600'FWL 1700' FNL Completion Date 9/3/75 Test Date 9~23/75 %Veil .No. No, 1 [ T°talDepth [ T/PaY I ?r°duclngInterval 9480' 116' 4730-5764 Producing Thru I Reservoir [ Wellhead I CSG. Size[ ~Vt/Ft. ] I.D. .' 107'F 55 '°F 9-5/8" 47_# 8.681 TBG'Size I ¥;t/Ft' ~ O'D' ]I'D' [ Set ~K]~ 2-7/8"] 6.5~ plg 3.668 2.441 555 Set @ 81~7' GaS Gravity [ Avl: Prod. ] ( S~a~0r ) Lelgth (I,) · 5536 GL[ 30~2 Cas-Liquid Hydrocarbon [ Gravity of Ratio MCF per Bbl. [ Liquid (Apt) Pipeline Connection None ~lultiple Completiq'n (Dual or Triple) Dual (Report for middle and lower zones) Type Taps Flange Type production from each zone OBSERVED DATA Flow Data . , Time (Prover) (Choke) Press. Diff. Tubing Casing Flowing No. of Flow (Line) (Orifice) h Press. Press. Temp, Hours; Size Size psig ~v psig psig st 0 2325 . Pkr:. set ~...,,, . !'0 . 4 026 2.0 150 21 . ~ 1930 .35 .5 " " 200 28 1725 20 .75 " " 230 32 1540 10 " .5 i' ' ·" " '280 40 1215 ...... 13 FLOIV CALCULATIONS ,,, Coeffl- , ,, , Flow Temp. Gravity Compress. 1~O. eientVw --'-k/h L Pressure Factor Factor Factor Rate of Flow (24 Hr.) psia F F F Q MCF/D t g pv ,.' ' '26-'.236]" 58.80 '"14.65 1.0'25 1.040 1~'0 '"1644 " : '77 53 .... " ........... ~. ' 1. 041 " " 2202.,.. .... ,, .... . 88.4'8 .... .~ ....... 1. 052 " " , . 2540 % ....... " 108.56 " 1. 049 " " 31,07 PRESSI:RE CALCULATIONS Caic BHP 2 2 p~2 P (:p~la) Pf 6rPs P~ p 2 - , cat w ~, _SI . 2666 ....... ~. 2223 4 .4,941,729. 2_~65._~77 . .... z. ..1~9i', ',ir, ,r 9 3,96.4,Q.81 3:1&3.475 a, .... 1782 1.3 . .. 3,175,5.24 3,932.032 4.. , 141~ . ~25 ....... 2,031,561 5.093.995 Absolute Potential: n 3981 I~ICF/D ;;00744 ~gion Engine,[me Cities Service 0il CERTIFICATE: I, the undersized, state ~at I am (company), ~d that I am au~or~ed by said comply to make ~ls repo~; and that ~ls report was pre- pared under my supervision and direction and that the fact~,~.-st~ted th~,l~ein are/~irue, correct and complete to the best of'my knowled,e. Slgll/ _ /~ ~ ~, ' t CITIES SERVICE COMPANY BOX 300 'tULSA ~ OKLAHOMA 74'! 0Z October 15~ 1975 State of Alaska Department of Natural Resources Division of Lands 323 East Fourth Avenue Anchorage, Alaska 99501 Attention: Mr. Pedro Denton Re: Our 01X6-5000358 State Lse #ADL-58801 Tract C-25-167 All Sec 2, All Sec 11- 14N-9W~ So M. Alaska Gentlemen: We have completed the Lewis River i-A well on the captioned lease as a well capable of producing gas in paying quantities. The lease provides for annual rental in advance on or before the beginning of each lease year prior to completion of a well capab].e of producing oil or~g~'s in paying quantities on the leased lands. The minimum royalty provision of the lease provides for a minimum royalty of $1 per acre payable at the expiration of each lease year that begins on or after a discovery of oil or gas'in paying quantities on the leased lands. Any royalty paid on production during a lease year shall'be credited on the minimum royalty for that year, It is our understanding, due to discovery~ minimum royalty of $1 per acre wo~id be due in lieu of advamce rental for the per~.od ending Noven~er 30~ 1976. Please confirm the status of the captioned lease, what type of payment should be made, and if this payment will be due December 1, 1975 or November 30~ 1976o This lease has a December i anniversary date. A reply at your earliest convenience will be greatly appreciated. Very truly yours, LANq3 DEPARTMENT Rental S~ction . Charles R. Neal CRN: ms CITIES SERVICE OIL COMPANY October 7, 1975 900 Colorado State Bank Building 1600 Broadway Denver, Colorado 80202 Telephone: :303-892-0263 State of Alaska Department of Natural Resources Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 ATTN: Mr. Hoyle H. Hamilton Chief Petroleum Engineer RE: Lewis River No. 1 Dear Mr. Hamilton: Enclosed please find the completion report for Cities Service Oil Company Lewis River No. 1 well. This well is considered a dual completion and two separate Form P-7 reports are included. Also included are two copies of completion schematic, tubing string description, sidewall core description, drill stem test summary, one copy of Halliburton's Formation Testing Report for Test 1-17, and one copy and one sepia for the mud log. In a separate box we are sending one sepia and one copy of the following electric logs: Compensated Neutron Formation Density Dual Induction Laterolog Borehole Compensated Sonic Proximity Log Compensated Formation Density State of Alaska Form G-I, Open Flow Potential Report, will follow in a short time. It is hoped that the enclosed information is sufficient. If there are any questions or problems, please contact me in Anchorage at 272-9441. WRH: kl Enclosures Sincerely, ,' ~-~ W. Randolp Hic s "~'''''' Drilling Engineer Western Region,i :~ Ii' ~"'."' ,:"~.. :! ' ' , . . SUBMIT IN DL ':CATE' . STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ii i ii ii i1,111 i ii WELL COMPLETION OR RECOMPLETION REPORT AND LOG* , b~ ........ ~ ~ ' , , Il. TYPE WELL: on. -~ ~VELL ~ w~LL DRY Other 7. b. TYPE OF COMPLE~ON: ~w ~ ~.o.,,~ ~.~.~ ~,.~ w t L f, ov ER EN n~C K ~ESVR. Other 8. , ~ ,. ~. NAME Or OPERATOR C~t~es Service O~1 Cmpany 3. ADDRES3 OF OPERATOH 1016 West 6th Avenue, Suite 420, Anchorage, AK.. 99501 4. n0cAx]o~ or wrL~ (Report location clearly and inaccordance with ang.~te~.. ~fl~m~L~ At lu~aee ! I ~ ~ '~ ' 'Lu ' ~6oo ~w~, ~7oo ~ x=3s~,87s[' lg~ ~, *' top prod. interval reporte~ below ~:2,681,0~ - Same OCT ~:) ~t total Same : :'V~<,~ :,~"J ~)j,.: i; ,~/~:,r~ :~':':'";~ 5/5/75 7/8/75 10/1/75 ! 118' KB HOW MY' ROTARY TOO~8 9480' T~ 5900' T~ 2 zones 0-9480 PRODUCING IN~VAL(S), OF ~S COMP~I~--~P, B~OM, N~ (~ AND Beluga Smnd, top 2279' This report 4730-5764' bottm 5863~ APt Nu~trmdC~ cou~ ........ 50-283 -20047 , LF~A,'Slq D~--'~IL;NATION A. ND SEItlA~ NO, ADL 58801 IF INDI~. A~E OI{ TiCIBE N~ UNIT,F~ OR ~kSE NAME Lewis River 9. W~L N0. 1 10. F~ ~D P~L, OR WI~CAT Wildcat il. SEC., T., R., M., (~OM HO~ OBJF-~IVE) Sec. 2-T14N-R9W, S.M. 12. PERMIT NO, 75-5' RT, GR, ~1~C)'~17. E~EV. CASINGHEAD 103 ' INTER%'ALS DRILLr. D BY .... CABLIgNA T001.8 WAS DIRECTIONAL SURVEY MADE · { Single shots ~ on bit trips ~Z~aE F~C~RIC A_ND OTHER LOGSRUI~I Compensated Neutron Formation Density, Dual Induction Laterolog, Borehole Compensa, ted ,,,Sonic , Proximity Los~ Compe..n..sated Formation Densit.y 25. CASING RECORD (Report all strings set in well) lo" I ' /LP 'l 48' ' 'Driven 20" [ 94# M-40 (}ut,rest)363 26" 13-3/8" [61 & 54.5#/ 3-5S I 1368' ' ' .. 9-5/8" [ 47# [Pll0~S~5 ~NR0 ~147' ~. ~NgR ~CO~ 6730~38, 698~7~9~, 5016-020~ 502~236 5535~65~ 5576%60.0~ 5675T88, 5707-15, 5728-32, 5736-52, 5757-~, W' casing gun, 4 shots/ft. '/,'~ ' C~%bLNTING RECO!R~ 456 sx Class G 1031 sx Class G 17-1/2"t 12-1/4" 1926 sx Class G 2-7/8" 5556~ 5080~ 2-7/8" 3906' 3~90' ACID, Si!OT, FD~C~ U~E, C~,~N'T SQL'~Z~, ~C, DEIPT2I IZ~'I'EiRVAL (MD) 6575-85, 5707- 15, 5744-52, 5757-64 DATE FIRST PI~ODUCTION I Pi~ODUCTION MEII{OD (Flowing, ga~ lift, pumpi~g--~Jze and type of pump) 7/18/75 [ Flowing . DATE O~ T~ST. [~O~S T~3~ .~ [~IOXE SiZE [PP~OD'N ~g O~D~ / ' ! I o WBING ~X~LNG P~SU~ ICAL~~ OI~BBL. ''850# I 3448 I 0 1o M'. ~".S~,mo~ o~ ~.~ (go~, ."~ lo~ I-% ~.~a, ~.) Vent ed ,,, A.%IO uN"r PULLED None None None None A.MOUNF /,.ND KIND OF MA'I~ER/'AL USED 20'00 gal pad, 2000 gal w/1 ppg sd, 2000 gal w/2 ppg, 2000 gal w/2 ppg, total sd 14000#, tara' fluid 10,000 gal, 150 'ball sea .......e ~S 30. PRODUCTION · WELL STATUS (Producing or ~,,u~-~ Shut in · GA2.,~-MCF. WAT~%--13BL. [ GAS-OIL ~%TIO 6896 ! o I I o ,, I m ..... . [ J. O. Scott Tubing description, mud log, DST reports, completion strin$ diagram .33. 1' hereb~ certify th:'~/thg-~oreg(~lng and attached tnf~.rmation 1~ complete an(t c.rrect aa d,-t.rm~,,ed fr,,m all-av'ailable r~eurd~ :/,~~~/. ~ ,,,~m ProdUct ion Manage.r 10/7/75 *(See Instructions and S~ces for Additional Data on Reverse Side) INSTRUCTIONS C~neral: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this fo~m and in any att.~chments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple complbtion), so state in item 20, and in item 22 show the pfcJuci~:o interval, or intervals. top(s), bottom(s) and name (s) (if any) for only the interv,~l r6ported in item 30. Submit a separate report (page) ori this form, adequately identified, for each addition~l interval to be separately produce~, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental recD"ds for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this forrn for each interval to be separately produced. (See instruction for items 20 and 22 above). 0C¥ g g75 34. SUMMAIt¥ OF FORMATION T~'I'S IN('I, UI)IN(-' INTEI{VAL, T~'rED. Pll~UIIE DATA ~ ~cOv~HI~ OF OIL. GAS. ~. G~IC MARK~ WAT~i AND MUD Drill s tm' test - su~a~ agtached , , Beluga Fomation 2279 ' Same Tyonek Fomat~oh 586~~ Bell Island Fora. 91~2~ ' Ch~ckaloon 9~1~ ~ Total depth 9~80 ~ i i i i i i ~ i ii L Sidewall core analysis attached CONFIDENTIAL CORE LABORATORIES, I'NG. I',,~o1,,,,,,, /¢,,.,,,,n,o,~- /:',,~,~,~,,,-,',,g DALLAS~ TEXAS 75247 June 30, 1975 Cities Service Oil Company 900 Colorado State Bank Building 1600 Broadway Denver, Colorado 80202 Attention: Mr. B. L. Tompson Subject: Core-Analysis Data Lewis'River #1 W/C Field Mat-Su County, Alaska Gentlemen: PercUssion type sidewall core samples recove red from the subject well were submitted to our Anchorage laboratory For analysis. The results of these analyses are presented in the accompanying report with a general iithologicai description of the samples. These cores were submitted for permeability, porosity and fluid saturation determinations. We sincerely appreciate this opportunity to serve you and trust we will be called on again in the future. Very truly yours, JAC:sme CORE LABORATORIES~ INC. District Manager CaliFornia Professional Reg. No. P- 1176 UNITED 5T AT(S CANADA ~OUTH AMERICA EUROPE AFRICA AU$1RALIA Company \Veil Field__ Count'__ Ltml'. LN SAF4~)LE CONFIBENTIAL CiHes Service Oil Co. Lewis River ~ 1 Mat- Su State_Al aska PlUM - o¥ P irOl · I Lt · [~ou I - ·Oil DEPTH . PERMEABILITY MIt. LIDARCY~ CORE LAi.]ORA'FC)RIES.' INC. l'etrolcum Rcscn,oir l:'ngin¢cring DALLAS. TEXAS CORE ANALYSIS RESULTS Formation Core Type.~ Sidewall Drilling Fluid_ Elev ..... Loc-~tion Lithological Abbreviations IANOY * IDY FINE - IHALY - IH( MIDIUM LIMY - LMY COANt[ POROSITY PER C i.~ ~ T I TOTAL CENT I OIL WATEIq Page No.. Fi]c_ BP-3-353 A n alpts_ _~S P_._ IAMPLE DEICRIklTliON ~V~OX o 1 2 3 4 5 6 7 8 9 !0 11 12 13 14 15 16 17 !8 19' 2O 21 22 23 24 25 26 27 5030 5579 5684 5747 5935 5943 6120 5582 5585 5588 5591 5673 5677 5707 5745 5902 5968 5972 6092 6094 6 !04 7160 7413 7620 7730 7873 7890 2.9 7.5 16.0 60.0 133.0 57.0 210.0 2.8 18.0 3.2 12 14 22 16 0.3 8.4 13 36 '75 4.8 9O 282 8.9 13 17 24 23 17.8 0.0 74.3 20.1 O. 0 60.4 17.0 0.0 60.8 20.7 O. 0 57.4 23.6 3.0 59.4 20.7 0o0 59.8 12.2- 0.0 53.2 23.1 3.0 72.2 23.0 2.9 59.4 20.2 0.0 61.4 21o7 0.0 65.2 27.5 0.0 45.1 20.2 0.0 58.3 21.6 0.0 61.8 11.8 0.0 73.7 15.0 0.0 60.4 19.9 2.4 61.2 24.6 0.0 71.6 25.0 0.0 66.9 18.1 0.0 62.7 26.1 0.0 75.0 24.5 1.5 63.2 18.9 0.0 70.7 19.2 0.0 63.4 21.3 0.0 54.3 23.6 0.0 71.3 24.3 0.0 62.5 ss, v fg-v slty, no flu ss, vf-fg, slty ss, vf-fg, slty ss, F-mg, ely ss, £g, ely same as above ss, £g, carblame ss, uf-fg, slty ss, v f-rog, clarb lam, sJty same os above ss, vf-fg, ely, slty same os above same as above, corb lam same as above si Pst ss, vfg, slty, sc carb cong., tr, flu, yellow ss, vf-fg, ely ss, f-rog, cly same as above same as above ss, vf-fg, ely, carb lam ss, vf-fg, ely ss, f-rog, ely ss, vf-fg, ely ss, vf-fg, ely ss, m-cg, ely 'rhes~ analy.es, ,,I,i,~,m% .r ;nte, l,,etatl-n.~ a,e basr(I (m ,,bservations and materials ~Upl}lied ~[ the clienl to wh,.n, ~n(I f,,, wh(,~e ex,'l.~,v~ h~*/lzili,*fl,,h','t,.d u','. COle Inc. 3 a'~,4 7 (6-74) ". CITIES SER¥1CE OIL. COMPANY ' ' ~ .... Dai~.JWell History - Interim Report Page 18 , INSTRUCTIONS: int~im Reports sba'It be compJeted and submitted with the Final Report for the Well Interim Reports ore required for may also be used for recording daily work on significant workOvers. The descripti~n:~o~:~ork pe~fGrmed On I~tqrim Re~6rts should be · complete, report of each days Drilling Activity. On significant wells the Tulsa Office may request Interim R~tS-os~'~ L.I='ASE / UNIT NAME AND WEL, I. NO. Lewis River No. 1 COUNT Y - P AIR ISH - ST A T E - PIROV INC E Kenai Boroushl Alaska, DATE AND DEPTH 7/15/75 8,000 7/16/75 8,000 7/17/75 8,000 IR EGION' · Western FIELD OR PIROSPECT NAME AFE NUMBEIR Wildcat 9-057001174 DESCRIPTION OF WORK PERFORMED 71 days TIGHT HOLE PBTD: 8,000 ' PreSent Operations: Prep to PU 2-7/8" tubing Remarks: Finish GIH with DST tools 1/2 hr. Push BP.7,432-795' 1-1/2 hrs. Open tool 7:23 AM, close tool 7:43 AM, SI @ surfac~ 3/4 hrs. SI 1 hr. Open tool to atmosphere 3/4 hr. Close tool and reverse out 2 hrs. POOH with test tools 2-1/2 hrs. Service tool 1 hr. RIH with DST tools, no cushion 2-1/2 hrs. Set packer @ 7,677' 1/2 hrs. Open tool 5:55 PM, SI @ surface, closed @ 6:10 PM, 2 Psi on DP 1/4 hr. Close tool 1 hr. Open to atmosphere, very weak blow, well died 15-20 rain, regained very weak blow 2 hrs. Close tool, release packer and ret BP 1/2 hr. POOH to 5,570', appeared to have lost BP 3/4 hr. RIH to rec BP 1-1/2 hrs. POOH, rec BP, rec 76' brine water (9.9+) 3-1/4 hrs. Breakdown tools, rec charts 3/4 hr. Installing board 1 hr. DST #1 with diesel cushion T128° (Bomb 7,664'); IHP 3988, 1st FP 2632, lst' FFP 2632, 1st SIP 3148, 2nd FP 2632, 2nd FFP 2632, 2nd SIP 3000, FHP 3988. (Bomb 7,690'); IHP 3992, 1st FP 2621, 1st FFP 2621, 1st SIP 3119, 2nd FP 2621, 2nd FFP 2621, 2nd SIP 2995, FHP 3992. DST ~/2 T1300 (Bomb 7,664'); IHP 3988, 1st FP 49#, 1st FFP 49#, 1st SIP 197#, 2nd FP 49#, 2nd FFP 74#, FHP 3988. (Lower Bomb 7,690'); IHP 3992, 1st FP 25#, 1st FFP 50~;, 1st SIP 201#., 2nd FP 50#, 2nd FFP 50~/, FH]? .3992. · 72 days PBTD: 8,000' ' Present Operations: Going in hole for DST #3 Remarks: Rigging tubing board 4-1/2 hrs. Rigging up tubing tools 1 hr. Cut and slip drilling line 3/4 hr. PU 249 jts 2-7/8" tubing, 7,7.91' 10 hrs. CBU 7,791' 1-374 hrs. POOH and strap tubing 3 hrs. Change rams in. BOP 1-1/4 hrs. PU DST tools and start in hole 1-3/4 hrs. 73 days TIGHT HOLE PBTD: 8,000' ' ' Present Operations: WOO Remarks: RIH for DST #3 4 hfs RU manifold and set packer @ 7,683' open tool @ 9:43 AM 3/4 hrs. Continuous weak blow increasing gradually last 2-1/2 hfs, gas to surface 5 hrs 47 rain 6 hrs. Taking SI pressure 4 hrs. Trying to unseat packer, pulled loose with 40,000# 3/4 hr. POOH, rec 39 stds 3,500' of fluid 9.8# brine water, found TIP valve partially open, probably opened while working packer loose 4 hrs. Lay down DST tools and rec charts 1-1/2 hrs. Lay down Daly Jars and DC 1-1/2 hrs. WOO 1/2 hr. PROCEDURE REF. 123.0.19 SUBMIT ONE COMPLETED COPY TO E& P GENERAL OFFICE - TULSA CITIES SERVICE OIL COMPANY ~i'~i Well History- Interim Report , ~ INSTRUCTIONS: Interi'm Reports shall be completed and submitted with the Final Report for the well. Interim Reports are required for all drilling wells and may also be used for recording doily work (m sign,f,cant workovers. The descri-pt.~on c~f wgrk perfc~rmed on. Jnterlm~Reparts should be a complete report of each · ' , . r, ;.- ; · .. ' ~ ' ~- ' · ~ /'. days Drilling Activity. On significant wells the Tulsa Office may request Interim~l~l~a~t.s 6i a. iJ~ee~t:4'e fi(Jl~lJout~.'..~ ,~- LEASE / UNIT NAME AND WELL NO, Lewis River No. 1 COUNTY - PARISH - ST ATI[ - PROVINC Kenai Borou~h.~ Alaska DATE AND DEPTH 7/18/75 7,650 7/19/75 5,900 7/20/75 5,900 FIELD OR PROSPECT NAME. Wildcat DESCRIPTION OF WORK PERFORMED R£GION Western AFE NUMB.ER 9-0570011-4 74 days TIGHT HOLE PBTDt 7,650' ~ DC: $34,160 CC: $2,437,202 (7/17/75) DC: $17,154 CC: $2,454,356 Present Operations: DST #4 packer ~6,060', peri 6,097-102'. Open 5 rain, moderate blow, SI 1 hr. Open 6 hrs, moderate blow, GTS 1 hr, 45 min. Est 850 tuFt/day. Lit flare, had 1-2' 'flare for remainder of test. SI 6 hrs. Remarks: Wait on wireline 5-1/2 hrs. RU and run Junk basket 3/4 hr. Run BP and set same @ 7,650' 1 hr. Peri 6,097-102' 4 shots~fl 1 hr. Rig down 1/2 hr. PU test tools and 6 DC's 1-1/2 hrs. RIH, no cushion 2-3/4 hrs. $~etpacker_ C8 6__~_q~060' , bottom 6,077', open tool 5:20 PM, mod- erate blow, closed 5:25 PM, SI 1 hr, open 6:25 (6 hrs) moderate blow decreasing @ 7:00 PM, GTS @ 8:10 PM, est 850 CuFt, lit flare @ 8:27 PM 1-2' flame, continued weak flame for remainder of test 1/4 hr. Closed 4-1/2 hfs. 75 days TIGtiT I~-LE- - -' PBTD: 5,900' (peri 5,707-15') '' Present Operations: Circ and c°nd hole. DST #4. cont'd. Rec 320' brine water, 1st IFP 137, I$IP 335, 2nd IFP 152, FFP 158, FSIP 630. Remarks: Completed DST #4, POOH, ran bridge plug and set ~ 5,900'; Peri 5,707-15' 4 shots per ft. PU test tools and RIH 'for DST #5, Pack- er @ 5,661, open tool 5 rain FTS 2 rain, 630 Psi on 1/4" choke in 5 min. SI I hr. Pressure on tubing, bled to 50 Psi while taking SI. Open tool @ 12:23, pressure on tubing cont'd to dec to 37 Psi @ 12:39, 11 Psi ~ 1:00 AM, inc to 15 Psi @ 1:10. Had gas bubbles coming up annulus @ 1: 10, closed tool and open reverse circ sub @ 1:15 AM. C10sed pipe rams and reversed out 3500 strokes. I circ, opened rams,' fluid dropped in annulus flowing out annulus, closed rams and pumped 300 strokes. DC: $19,809 CC: $2,.474,165 76 days TIGHT HOLE PBTD: 5;900' (peri 5,707-15') Present Operations: Running DST #6. DST #5 cont'd. 1st IFP 866, ISIP 2843 (possible packer leak), 2nd IFP 421 (20 min. 438), FFP 423, FSIP 2690. Remarks: Unseated packer, removed manifold, ran 1 std, PU Kelly, re- versed out with circ sub @ 5,720'. Cond and raised cut of brine water to 10.1+. POOH, laid down test tools. Changed rams to 4-1/2, tested Hydril to 1750. PU DP tools for DST #6. RIH, set packer @ 5,648'. Opened tool with weak blow. PROCEDURE REF. 123.0.19 SUBMIT ONE COMPLETED COPY TO E& P GENERAL OFFICE - TULSA 32.*,47 (6-74) INSTRUCTIONS: Inre~m Reports ~hall be completed'end submitted with the Final Report for tile ~ell. Interim Report. ore required for oil drilling welle and may also be used for recording daily work on significant workover~. The description of work performad on Interim Report~ ~hould be a complete report of each day~ Drilling Activity. On significant wells the Tulsa Office may request interim~R:~6~]~ ~ a~'t~e~'~ fil~d:~but~ ~ .. ~ :y.,~ ........ ,. ~.~, ~ LEASE / UNIT NAME AND WELL NO, Lewis River No. 1 i F IELD OR PROSPECT NAME WiIdcat COUNT Y - PAR ISH - ST AT E - PRDV I NC E Kenai Borou~hl Alaska DATE AND DEPTH 7/21/75 5,900. 7/22/75 5,900 7/23'/75 5,900 REGION Western AFI= NUMBER ~-0,5700~.1-4 DESCRIPTION OF woRK PERFORMED 77 days TIGHT HOLE PBTD: 5,900 ' DC: $12,565 CC: '$2,502,323 Present Operations: Swabbing DST #7. DST #6 Cont'd, packer @ 5,648', perf 5,707-15', tool opened 4 hfs, SI 4 hfss POOH, rec 90' brine water. Hyd 2969#. IF 93.4, 82, 240 min, SI 82f;. .124 min 90#, 125 min 938#, 134 rain 858#, 144 mtn 845#, 154 rain 845#, 169 rain 845#, 170 rain 11.28~, 179 rain 1132#, 190 rain 1134#, 201 rain 1139#, 212 rain 1146#, 223 1154#, 234 min 1161#, 245 min 1168#, 259 min 1185#, F Hyd 2978~. Remarks: 1/2 hr SI. 2-1/4 hfs released packer and POOH. 1 hr lay down test tool. 3/4 hr change pipe rams from 4-1/2" DP to 2-7/8" EUE. 2-3/4 hfs lay down 60 its 2-7/8" EUE. 1-3/4 hfs PU test tool. 2-1/4 hfs WIH with DST #7. 1 hr rig test manifold, 1 gal pipe lax down in work string, set packer @ 5,676', tail @ 5,694'. 3/4 hr break form, pressure annulus to 1500#, pump 34 bbls diesel/surfactant, surface pressure inc, 5 bbls, form broke @ 3800#, 10 bbls 3 BPM @ 3400#, 5 bbls 1-1/4 BPM @ 2800#. Pump total 54 bbls, shut down pump. Pressure drop to 2500#. 3 hr decline to 2000#. Open pit, rig to swab. 3-1/4 hfs swab @ 900' from surface, fluid entering tkbing,, swab to 2,150', small amount fluid, rise in tubing. 78 days TIGHT HOLE DC: $20,622 -CC: $2,522,945 Present Operations: Perforating Remarks: Swab to 2,300'. 1 hr repair sand line. 3 hr swab to 4,200' 1 hr check fluid rise. 1/4 hr swab to 4,200'. Rec 75' fluid. 5-1/4 hrs swab each hour to 5,300', no fluid rise. 1-1/2 hrs release packer and reverse out. 1 hr SI. 3-1/2 hfs POOH, lay down test tools. 1/2 'hr change rams to 4-1/2" DP. 2 hrs WIH open ended to 5,900'. 3 hfs circ and cond to 10.1#. 1-3/4 hrs POOH. 3/4 hr rig to perf. Perf 5,757-764', 5,744-7~~'- Prep to perf 5,707-715'. 79 days TIGHT HOLE PBTD: 5,900' (perfs 5,675-685', 5,744-752', 5,757-764', reperf 5,707- 715'. DC: $27,614 CC: $2,550,559 Present Operations: Flowing to clean Remarks: 4 hr perfs. 1 hr PU test tool. 2-1/4 hfs WIH for DST #8 (no water cushion). 3/4 hr rig manifold, .set packer @ 5,620', tail 5,637'. Open tool 12:50 PM, 7/22/75. 16 hrs testing, GTS 21 rain, 10:00 PM. Streak fluid H20 and diesel oil (comp fluid). Flow on 1/4" to 3/4" choke, gas increasing, 3/4", 130#, estimated 2,000 Mcfpd. PROCEDURE REF. 123.0.19 SUBMIT ONE COMPLETED COPY TO E& P GENERAL OFFICE - TULSA CITIES 'SERVICE OIL COMPANY i~'~ D~!l~l Well History -Interim Repot INSTRUCTIONS: Interim Reports s~el.l ~e completed end submitte~ with the Finel Repot, lot the well. I,nt~rim R~ortl are requi~ed ~or ell &illin~ wells am may also be used for recording daily work off significant workovers. The descri~tf~;°~~ w~tk performed o~. J~ri~port, ,hould be a complete report o~ each days Drilling Activity. On ,ignificant wells the Tul,a Office may request Interim ~6~ti a'ia.ih'ees']~:"~il~'~ ~ut. "~ LEASE / UNIT NAME AND WELL NO. Lewis River No. 1 COUNTY - PARISH - STATE - PROVINCE Ke.na.i Borougha Alaska DATE AND DEPTH 7/24/75 5,900 FIELD OR PROSPECT NAME Wildcat 7/25/75 '5,900 7/26/75 5,640 DESCRIPTION OF woRK PERFORMED FIE(JlON Western AYE NUMBER 9-0570011--4 80 days TIGHT HOLE PBTD: 5,900 ' Present Operations: Testing perfs 5,675-685', 5,707-~15', 5,744-752', 5,757-764 ' Remarks: Time 12:57 PM, surface pressure open tool, choke 1/4". 3:00 PM, 220/;, 1/4". 3:00 PM open on 1-1/4". 8:00 PM 33# 1-1/4". 8:15 PM 3/4". 8:42 PM 52# 3/4". 8:52 PM change choke to 1/4". 9:27 PM 410# 1/4". 9:27 PM change choke to 3/4". 4:30 AM 130# 3/4". 4:30 AM change choke to 1/4". 5:30 AM 930# 1/4". 5:30 AM change choke to 3/4". 7:00 AM 152# 3/4". 7:15 AM turn thru separator 3/4". 10:30 AM 282# 3/4"-1,600 Mcfpd. 12:30 PM 282# 3/4". 12:45 PM 540~ 1/4". 1:30 PM 1,025# 1/4". 1:45 PM change choke to 9/64". 2:30 PM 1,975# 9/64". 2:30 PM change choke to~ 1/8". 11:30 PM 1,810# ~1/8"-420 Mcfpd. 12:10 AM change choke to 11/64". 3:45 AM 1,525# 11/64". 4:00 AM change choke to 15/64". 4:30 AM 1,400# 5/64". 81 days TIGHT HOLE PBTD: 5,900 ' Present Operations: Shut-in for pressure buildup Remarks: Cont'd testing perfs 5,675-685', 5,707-'715', 5,744-752~, 5,757-764' @ varying choke sizes for back-pressure test. SI well @. 8:00 AM 7/24/75. Flow test data as follows: Time P, Mtr, Psig ah~ in H?O., T.~ OF orifice in. Calc Rate Mcfpd 10:30 AM 200 70 131 1.5 1600 12:30 PM 205 68 100 1.5 1720 1:00 PM 240 80 97 1.25 1390 7:45 PM 225 30 96 .75 290 8:30 PM 225 96 96 .75 530 11:30 PM 225 60 83 .75 420 3:45 AM 220 80 85 1.0 860 5:00 AM 220 78 94 1.25 1300. 8:00 AM 220 80 97 1.25 1330 SI from 4:30 AM to 8:00 AM 7/24/75, tubing pressure declined @ con-. stant gas rate on choke size of 1/4" as follows: 4:30 1315; 5:00 1200; 5:30 1140; 6:00 1100; 6:30 1030; 7:00 975; 7:30 950; 8:00 925. DC: $11,553 CC: $2,591,073 82 days TIGHT HOLE PBTD: 5,640 ' Remarks: Completed 24 hrs buildup test. Closed tubing at top, opened bottom tool, observed TP 3-1/2 hrs. 2320 Psi. Blew down 1/2 hrs, Reverse out 1-1/2 hrs. POOH with test tool, lay down 4 hrs. Rig to perf, set c~tainer ~-1!2 hrs. Perf 5,576-586' 3/4 hrs. PU DST No. 9 ~est tools,' W~rs Connect test manifold 1/2 hr. Open tool, weak blow, no gas to surface in 2 hrs. 1/2" choke, FTP 19 Psi, SI for BHP. DC: $12,277 CC: $2,603,3~0 PROCEDURE RFF. 123.0.19 SUBMIT ONE cOMPLETED COPY TO E& P GENERAL OFFICE - TULSA CITIES SERVICE OIL COMPANY i,J%:!~ "~-::i'"' ~i ,:;~ i~!/~ t"~:J~aily Well History- Interim Repor Pa.~_ .22 may also Be used. for recording daily wore on significant wor~over~. The descripUon ~"~O~k~p:e~'on I~f~rim Re r doy~ Drilling Activity. On signitic=nt weil~ the Tuls~ OHic® ma- ~e-ue-t' ' ' ' ~ / :~,...,:~;~;~,:~...~ ..... po t~ s~ould be = complete report of each LI:'ASE / UNIT NA-ME AND WELL NO. Lewis River,, No. 1 COUNTY - PARISH - STATE-- PROVINCE Kenai Borou§h, AZaska DATE AND DEPTH 83 days TIGHT HOLE 7/27/75 5,640 · - i REGION I · ! Weste~n-' F'I£LD OR PROSPECT NAME ' I AFE NUMBER Wildcat 9-0570011-4 DESCRIPTION OF WORK PERFORMED 7/28/75 5,640 7/29/75 5,560 PROCEDURE REF. 123.0.1¥ PBTD: 5,640' DC: $11,743 CC: $2,611,093 Remarks.: Running DST ~9, peris 5,576-586', packer @ 5,544'. SI for BHP, 4 hrs, open tool ~ 8:30 AM on 1/4" choke wifh--3%~F~-'. 8:35 AM 49~/, 8:40 AM 75~;, 8:45 AM 95#, 8:55 AM 135 ~, 9:00 AM 145~, 9:05 AM 159~, 9:10 AM 165~;, 9:15 AM 172~, 9:20 change to 3/4" choke, 65~, 9:25 AM 170~, 9:30 AM 183~, 9:35 - 3/4"+ 3/4" chokes, 9:40 turn thru sep-. arator, 10:45 AM on 20/64" choke 900~, 11:15 AM on 29/64" choke. Run- Ring 4 pt back pressure test 11:15 AM to 4:20 PM. SI @ 4:20 AM for 24 hr buildup. Test results .were as follows: Choke Time Meter Diff P . Temp size FTP Press Orifice _tn. H20 o F Rate 11:15 AM 29/64" 475 Psi 220 Psi 1-1/2" 97 ~ 2100 Mcfpd 1:40 PM 29/64" 500 Psi 230 Psi 1-3/4" 58 110 2290 Mcfpd 4:00 PM 29/64'" 560 Psi 250 Psi 1- 3/4" 63 95 2514 Mcfpd 4:30 PM 10/64" 1525 Psi 168 Psi 1-1/4" 25 98 642 Mcfpd 8:I5 PM 10/64" 1900 Psi 168 Psi 1-1/4" 29 95 747 Mcfpd 9:00 PM 14/64" 1550 Psi 220 Psi 1 1/4" 80 90' 1440 Mcfpd 12:15 AM 14/64" 1550 Psi 220 Psi 1-'1/4" 73 103 1360 Mcfpd 1:00 AM 17/64" 1250 Psi 225 Psi 1-1/2" 86 103 2020 Mcfpd 4:15 AM 17/64" 1300 Psi 220 Psi 1-1/2" 80 102 1930 Mcfpd 84 days TIGHT HOLE P BTD: 5,640 ' Remarks: SI for buildup following DST ~9 - 85 days TIGHT HOLE PBTD: 5,560 ' · Present Operations: Running DST #10, peris 5,535-545', packer @5,496' Remarks: Comp pressure buildup DST #9. Opened tool with surface of DP SI. Surface pressure 2,~O5 Psi in 3/4 hr. Blew well down on 35/64" choke. After 2-3/4 hrs measured 3684 Mcfpd. SI @ surface 3 hrs. Pressure 2220 Psi. Opened c~rc sub, rev out, unseat packer, PU 1 std & RIH, hit bridge @ 5,585', 20,000f/ wt, unable to drop thru. PU and cite out, POOH and lay down test tools, strap out. Small ant grey sand in tail ~ipe. RU, run junk basket to 5,578', s.et ret~r @5,560_0_~ Peri 5,535-545' @ 4 shots/ft. PU test tools, RIH for DST Y/10. Open tool with weak blow, 1 Psi ~m 1/4" needle valve. Su~nary of bottomhole chart from DST #9: IHP 2905, IFP 70, FFP 113 for 2 hfs open, 4 hrs SIP 2671, after 4 hfs 2nd flow BMFP 762 (TP 500#), after 4 hfs 'flow 29/64" chok~ BHFP 875 (TP 5609), after 4 hfs flow on 10/64" choke B}[FP 2341 (TP 1900#), after 4 hrs flow on 14/64" choke BHFP 1946 (TP 1550f~) BIfF unstable still building, after 4 hrs flow on 17/64" choke BHFP 1655 (TP 1300#) BHP unstable. Pressure buildup: 0 hr 1655, ! hr 2598, 2 hr 2619, 4 hr 2635, 6 hr 2644, 12 hr 2663, 24 hr 2676 Last 30 mtn, no increase. ' SUBMIT ONE COMI"LI: I l:U ,~,? (6.?,) /'~ CITIES SER¥1CE OIL COMPANY Page 23' Daily Well History- Interim Repor INSTRUCTIONS: Inte;'im Reports shall be completed and submltted with the Final Report for the Well. Interim Reports are required for oil drilling wells an, may also be used for recording daily work on significant workovers. The description of work performed on Interim Reportl should be a complete report of each days Drilling Activity. On significant wells the Tulsa Office may request Interim Reports as a sheet is filled out. LEASE / UNIT NAME AND WELL NO. Lewis River No. 1 7/31/75 FI'ELD OR PROSPECT NAME Wildcat REGION Western AFE NUMBER · 9-0570011-4 COUNTY - PARISH-- STATE-- PROVINCE Kenai Borough, Alaska DATE AND DEPTH DESCRIPTION OF WOI~K PERFORMED ,,, 7/30/75 5,5'60 86 days TIGHT HOLE PBTD: 5,560 t Present Operations: Running DST f/il, perf 4,364-69' packer @ 4,308' Remarks: Tool open {~ith weak blow after 30 rain, had'23 .~F~~~' needle valve, opened to-pit on 3/4" choke gas to surface in 32 rain (2 rain after opening to pit). Pressure dropped to 1 Psi, est 5-10 Mcf, open total 120 min. Now taking 4 hr SI DST f/10 cont'd perf 5 535- · , 45'. Tool open 2 hrs, weak blow, SI 2 hrs; open 2-1/2 hrs, weak blow. SI 5-3/4 hrs,, open 1 hr, weak blow then SI 1-1/2 hfs, prep to POOH. POOH, rec 90 brine water. IHP 2876 , 1st IFP '62, FFP 62, 1st SIP 431 (2 hrs), 2nd IFP 62, FFP 62, 2nd SIP 1543 (5-3/4 hfs), 3rd IFP 62, FFP 62, 3rd SIP 848 (1-1/2 hrs). Perf 4,364-69', 4 shots per foot. 87 days TIGHT HOLE Present Operations: - DST fill, perf 4,364-69', packer @ 4,308' Remarks: Tool SI 3 hr 45 rain, gas bubbles in n~ulus. Opened tool on bottom, SI @ surface 5 rain 12t;, 20 rain 40~;, 50 rain 110#, 80 rain 172#, 110 rain 240~), 270 rain 310~. Opened on 3/4" choke, pressure to Iii in 60 min. SI 2 hrs 15 rain, more gas bubbles in annulus· Opened tool on bottom, SI @ surface 350~) in 60 rain, opened to pit on 3/4" choke, decreased to 6# in 35 min. Unseated packer, PU and reset p_~acker @ ~ Opened tool 3/4" choke @. surface 15 rain 2~, 30'mln 11#, 60 rain 15(~, 90 rain 171~, 120 rain 19#, 150 rain 2ltl, 180 rain 27#, 200 rain. 31# 210 rain 32t~, 240 rain 37#, 270 rain 38#, 285.rain 45#, 290 rain 135t~, changed to 1/4" choke, 295 rain 1851~, 300 rain 220t~, 330 rain 319~/, 360 opened on 3/4" choke pressure to 30~, very strong mist water, 420 1/4" choke pressure 365t~, 455 rain opened on 3/4" choke pressure to 48t~, 505 rain 1/4" choke pressure to 390t~, 540 rain 3/4" choke pressure · to 52f~, 585 rain 1/4" choke pressure to 417#, 600 rain 1" choke pressure to 67#. Turned thru separator 30 rain, tubing pressure 225#, 30 stable flow, 220 Psig 60" 80° 3/4 orifice 0.417 MMcf, SI. Will leave SI 6 hrs open for flow rate. DC: $15.675 CC: $2.663.13R CITIES SERVICE OIL COMP, . iY ~.Doily Well History - Interim Rep~r .................... Page ,2& ,~F-,"' L ~J ! i i iii ,.s nuc ,o. Hs: "--,'..'. ,..,,.d ,. 0,, d,,,,.. -.". - may also be used for receding doily wo~k ~ ~ignif,con~ workovers. Th. descripti~~rmed o~'l~terim Repo~t~ ~hould be o complete fep~ ....... ~1 · .'~ ~ ~ ', doy~ ~rilhng Achwty. On ~gmf~cant wails the ~ullo OH,c~ may requ~lt Intertm Re~r~.~,b~t II filled 'LEA$~.'-'/ UNIT NAM[ ~%ND Wi[I..I,. NO. Lewis River No. I COUNTY - P ARISN- ST&TI~' PROVINCE: Kena,:[ Boro, ugh~ Alaska DATE AND DEPTH 8/2/75 4,320 [ ,~EG,ON ' ' Western FII:'L.D OR PROSPI'CT NAMe. AF'E. NUMBIrR Wildcat '9-0570011=4 8/3/75 4,320 DESCRIPTION OF WORK PERFORMED 89 days TIGHT HOLE PBTD: 4,320' (perf 4,096-116') Present Operations: DST #12 Remarks: Open 60 mis, had 20 Psi on 1/2" needle valve in 30 min. Open on 3/4" choke. GTS 38 min. Had less than 1 Psi after 60 min. 2 hfs 12 min. Opened on 3/4" choke with 29 Psi decreasing to 1 Psi in 12 rain Pressure started increasing; had 80 Psi after 58 mis, 115 in 1 h; 33 min. Changed to 1/4" choke; had 175 Psi in 1 hr 58 mill. Changed to 3/4" choke; pressure decreased to 118 Psi and then gradually · increased to 210 Psi after- 5 hfs 38 min. Switched thru separatio~ equipment for 4-point test. 1st rate after 3 hfs 25 mtn on 3/4" choke: 2.314 MMcf with 350 Psi FTP. 2nd rate after 4 hrs .on 11/64" choke: 0.474 MMcf with 1575 Psi FTP. 3 rd rate after 4 hfs on 16/64" choke: 1.237 MM with 1300 Psi FTP. 4th rate after 4 hrs on 18/64" choke: 1.696 MM with 1015 Psi FTP.- SI' for 24 hrs buildup. DC: $14,681 CC: $2,727,288 -- Pressures from DST #11, 4,364-369' and 5,535-545'. IHP 2256, FFP 340. ~ 2276. 90 days PBTD: Time .(rain) BHSIP Time '(rain).. BHSIP SIP 0 351 SIP 50 "2~14~ 5 808 60 212l 10 1148 120 2140 1.5 1861 180 214.5 20 1998 240 2149 30 2086 - 300 2152.5 40 -' 2103 438 2154 ~ · TIGHT HOLg 4,320' DC: $11,668 CC: $2,738,956 ' Present Operations: SI for Bf~ 8/4/75 4,075 91 days TIGHT HOLE ' PBTD: 4,075' "- 'DC: $16,060 CC: $2,755,016 . Present Operations: Running DST ~14 Remarks: DST #12 cont'd after taking SIP. Opened to 25 mi.n on 2 3/4" chokes, 315# on DP. Put thru test separator 3/4" choke, 100 mill. After 100 mis 445(; DP, 315 sept, 46" 87° orifice 2" 3 206 MM After , , , · After 145 mis 445/) DP, 308 sepr, 48" 78° orifice 2" 3 198 ~. SI , , , · and reversed out. R l~~ker and RIH to 4,213' and reversed out. POOH, lay down test tools, RU and set retainer @ 4,075'. Perf 3',717- 7.25' 4 shots/fi PU tools, RIH, set packer ~ 3,'686' for DST (/13 , · Open 'tool, strong blow pressure to 29# in 15 mis 1/2" needle valve. Open on 3/4" choke, GTS 18 rain, well died after 50 min. SI 2 hrs, 20 min. Open 40 mi.n on 3/4" choke, weak blow. Dead in 20 min. Unseat packer and reset open tool, weak blow and died. Reversed out. POOH, layed down test tools· Perf 3,647-651'. RIH with DsT ~14. Open tool @ 4:50.in 5 mis, 10 Psi on DP on 1/2" needle valve, 10 rain 21 Psi and PROCEDURE REF. 123.0. and 15 mtn 32 Psi.. Open on 3/4" choke, (;TS, 16 mtn had 1 Psi 20 mi.n. "~ CITIES SERVICE OIL COMP~ ~ ally Well History- Interim Report Page 25 ,~=: :. ~ ~ ~. i i iii i r l i i i INSTRUCTIONS: In;.;'Gm Reports .hell he completed and submitted with ?'L~-~]~01~,~el~jr~ fe~"~!.the ~1'~1t;I I~t~lt%,l? Reports ore requi,ed fo, oll drilllng well. ~ . . , .~ .~~.~ ~ ~ . may else. be u~ed fo~ ~ecord~ng daily w~rk ~n ~ignif~cant workove~l. ~He desc~,pt~on~Q~,~.~k~ff~o~rim Repo~t~ ~hould be o complete ~eport of e~ days Drilling Activity. On significant well. the Tulsa Oftice may ,eque,t Into, ia ~ep~/~.~il filled out, LEASE / UNIT NAME AND WELL Lewi's River No. ! COUNTY - PARISH- STATE- PROVINCE Kenai Borough; Alaska ~I£GION Western FIELD OR PROSPECT NAME: AFl:' NUMB£1q 4 Wildcat 9-0570011- DATE AND DEPTH 8/4/75 DESCRIPTION OF woRK PERFORMED Pressures from DST (;12 (Perf 4,096-116') lB 2105, FRP 2097, FP lac rate 532 Psi, FP 2nd rate 1763 Psi, FP 3rd rate 1462 Psi, FP 4th rate 1186 Psi. Time (rain) BHSIP Time (rain)' BHSlP SI?'' 0 1186 szP 300 '1973 5 1641 360 1983 10 1741 480 1993 20 1841 600 2001 30 · 1862 720 , 2005 60 1895 840 2007 90 1917 1080 2012 120 1928 1320 · 2015 180 1946 1512 2018 '240 1961 · 8/5/75 Pressures from 'DST--#13 IHP:-1900, IFP 180, FFP 173. lime, (rain) BHSIP Time SIP 0 - 173 SIP 70 10 ' 255'" 80 '-.-20-- - .352-(jumped 534). 90 30 534 94 40 534 135 50 538 141 60 543 BH$IP 583 : 599 (J~rmped 772) 772 .(jumped 9/+1) 952 Opened tool (74), IF 259, FF 259. SI (275-300 rain while reversing). 259~313, 18 rain later 313~372. FHP 1919. 92 days TIGHT HOLE DC: $11,443 CC:-$2,766,459 Present Operations: DST #14 continued Remarks: SI 2 hrs. Open 1 hr on 3/4" choke, final pressure. 3-1/4 Psi. SI 2 hrs.. Open 4 hrs 17 rain on 1/4" and 3/4" choke, max pressure 197 Psi on 1/4" choke. SI 1 hr 58 min. 'Open on combination 1/4" and 3/4" choke @ 7:18; 7:21 slug of water to surface, 7:25 167#; 7:30 7:35 23(;; 7:40 17#, 7:45 154/; 8:00 15# changed to 1/4" choke 8:05 83~, 8:10 125#, 8:i5 155#, 8:20 176~/, 8:25 187~/; 8:30 197~/, 8:35 207~/~ 8:40 215~;; 8:45 220~/; 8:50 225#; 9:00 230(} opened 3/4" choke @ 9:00, 9:05 34(); 9:30 17~/; 8:35 17#. SI 2 hr 57 min. Open 12:32 light spray water @ 12:34; 12:36'100~/ on 3/4" and 1/4" choke, 12:45 35(/; 12:50 12:55 20#; 1:00 20#. Switch thru sept equip; 2:00 220# on DP. Flo~ rate-30" '65° .5 133 Mcr, 2:30 133 Mcf. SI @ 2:30. PROCEDURE REF. 123.0.19 SUBMIT ONE COMPLETED COPY TO E& P GENERAL OFFICE - TUL~ ' CITIES SERVICE OIL COMP. ~iY SEP 1 b ~975 D~ Well History - Interim Rep~ Page 26' - r . . T.~ ?. ~.~.. . . ~ .~ .. ~. INSTRUCTIONS: Int.~. Repot,, ,boll be compI.ted "n~ ,.bmitted with the P!4it~~o~,.~e ~l.l. ~,~o., o,e ,e,vired '0, oil al, filing wells goyl ufi,~ing nctivily. Un lignHicont weitl fbi Tulsa Office moy requelt Interim Reportl o~-o I~tJ~'~i' f]lted out. I. EASE / UNIT NAME AND WELl. Lewis River No. ! COUNT Y- PAHISH--ST'AT E- PHOVINCE Kenai Borough, Alaska , DATE AND DEPTH 816/75 8/7/75 , r 93 days TIGHT HOLE FIELD OR P/~OSPE:CT N&MI:' Wildcat DESCRIPTION OF woRK PERFORMED N£GION -- Western AFI=' NUMB Ell! 9-0570011-4 DC: $11,515 CC: $2,777,97.4 - Present Operations: Swabbing - Remarks: DST #14 cont'd. SI for buildup 1-1/2 hrs. Flowed to pit 1 hr. Reverse circ 1 hr. Unseat packer, POOH 4-1/2 hrs. Change pipe rams 1-1/2 hrs. PU tools for DST #15, bottom tubinj~ 3,734 2-1/2 hrs. RU manifold pump, 20 bbls 57~ KCL in tubing followed by 9 bbls diesel, spotted KCL on perfs. PU 1 stand, set packe~ @ 3~ Closed rams, pumped into formation ~ 1700 Psi. Pump~ in 3 BPM @ 2,000, 5 BPM @ 3,000. Pumped in total of 12 bbls, shut down pumps 2,000# TP. Shut well in 1 hr. Open well 750 Psi, flowed back 15 bbls diesel in 4 hrs' RU swab, swabbed 3 hrs, have rec all diesel and 5 bbls of water, show gas, swabbing .from 2,000', 12 hrs. Pressures from DST ~14 .... IF 165 FF 276 Time BHSIP · 0 276 5 399 10 503 15 628 20 732 30 907 40 1132 50 1391 70 1690 80 1699 lO0 1707 127 1716 2nd . ii "IF 264 FF 273 Time BHSIP 0 273 5 426 10 564 15 684 20 802 30 1029 40 1257 50 1531 70. 1687 80 1693 100 1694'- 120 1696 180 1705 240 1708 272 1714 3rd 4th 5th IF 286 ._ FF 357 Time BHSIP _ 0 357 - 5 498 10 658 20 993 - . 30 1247- 4O 1484 5O 1604 80 1643 100 1655 139 1670 IF 365 IF 286 -FF'-- 200-~- Time BHSIP Time BHSIP ~ 200 0 382· 5 306 5 667r. 10 530 10 897 15 705 .15 1134 · 20 917 20 1298 30 1274 30 1494' 40 1501 40 1521 50 1545 50 1540 80 1580"-' 80 1567 100 1594. 100 1582 120 1598 12~ 1593 150 1615 150 1605 209 1627 180 1614 210 1622 266 1631 FHP 1834 @ 3606 92° 94 days TIGHT HOLE DC: $25,970 CC:$2,803,94& PROCEDURE REF. 123.0.19 SUBMIT ONE COMPLETED COPY' TO E& P GENERAL OFFICE - TULSA , ~ /." CITIES OIL ¢OMF. i¥ Page 27 L oily Well History.- Interim Repot · ,.J i..- ~ ~.~ . I,.~ l ~..~ INSTRUCTIONS': Inf~im Reports shell be completed end submitted' with the Final Report for the well. Interim Reports ore ~equi~ed fo, oil drilling wells may oleo ~e used for recording dmly work ~ s~gn/f,cont wo, kovers. ~he d~Tton ~f ~o~k ~e~for~'~n,~rim ~eporte should be · complete days Drilling Activity. On e,gmf~cont welle the Tulsa Off,ce may requeet In~RePo~te~os LEASE / UNIT NAMr AN[:) WI'Il. NC), Lewis River No. 1 COUNT Y - P ARISN - ST A TI:' - PROVINC E: . Kenai Borou Alaska DATE ANDDEp'TH 8/7/7.5 8/8/75 PROCEDURE REF. t23.0,803#, '2nd ]¥P 478, FYP 478, FII:'LD OR PI~OSPE:CT NAME. Wildcat DESCRIPTION OF woRK PERFORMED Iq£GION Western ?-0570011-4 Present Operations: Prep to POOH. Remarks: ' Floved veil to pit to clean up. SI @ 9:10 to rig dow~ swab- TP 1000 psi 40 min. opened to pit @ 9:50. Switched thru separator at 10:15 rate 272 MCF. 11:10 230 TP 220 Sept 281 MC]~, Shut In,TP 230 psi, 15 rain 835, 20 min 950, 25 rain 1075 30 rain 1200 psi, 35 rain 1275, 40 rain 1300, 45 mtn 1325; 50 min 1340, 55 min 1350, 60 min 1355, 65 min 1370, 70 mtn 1375, opened to pits 10 min switched thru separator 1.5 min 2~0 ~P 220 sept 306 MCF 25 min 245 TP 220 TP sept 305 MCF SI 10 min 255, 15 rain 500, 20 min 750, 25 rain 950, 30 rain 1075, 35 rain 1175, 40 min 1-215, 45 mtn 1250, 50 min 1275, 55 min 1300, 60 .mia 1315, 65 min 1325, 70 min 1350, 75 mtn 1350, 80 min 1365, 85 mtn 1375, 90 rain 1385, 95 rain 1395', 100 rain 1400, 105 rain 1400, 110 rain 1410, 115 min 1415, 120 min 1420, 125 min 1425,130 mtn 1425, 140 min 1430, 145 ._.min 1440, 150~.min_1440, Open_to pit blew down to 100'psi.had- fine mist _of water, Switch'thru sept 20 min 220 TOP 222 Sept 305 MCF Rigged up to 9cidize, Pumped 3 Bbls 5% KCL water 150 gallons 12% 'HCL 3% HF. &.1% L~i & .4I--Inhib & .4%.surfactant. Displaced with 3 Bbls KCL water, and 20 Bbls diesel. Maximum r~te 5 PBM @2700 psi. SI 15 min Opened well flowed 15 Bbls diesel and died, Swabbed 5 Bbls diesel and Well started flowing. ' Recovering emulsion and lots of' fine sand. SI 20 min to rig down swab. Open on 3/4 choke I hr ':-, 30# TP switched to 1/4 choke 40 min 1210# TP changed to 3/4 choke, found sand in choke, after 30 min 235 psi TP on 3/4" choke 80 245 TP 220 sepr 342'MCF 100 min 245 TP 220 sept 340 MCF 130 245 TP 220 sepr 375 MCF, 180 min 245 TP 220 sept 375 MCF. Opened by-pass reversed out recovered 2 Bbls emulsion and fine sand. Prep to POOH. 95 days TIGHT HOLE DC: $21,869 CC: $2,825-;813 Present-OperatiOns: DST #14A continued Remarks: 2-1/2 hrs POOH, laid down test tools. 1-3/4 hrs RU, set retainer 3,600', perf 3,084-94', 4 shots per ft. 1-3/4' hrs PU DST tools for DST (/15, RIH set packer @ 3,028'. Open tool 11:30 AM, strong blow 45 Psi, 3 rain on' 1/2" needle valve. GTS 5 rain, open to .pit pres- sure to 2# in 20 rain, 1.5# in 40 rain, O# in 60 min. SI for 2 hrs. 3pened tool 1 hr, no blow, unseat packe_~r POOH, rec 380' water 9.5# + 95' of sandy, silty mud. PU }ubing test tools. RIH set pa~r @3~033' ptnnped 20 bbls 5% KCL + 20 bbls diesel. PI @ 1600 Psi, maximum 2-1/2 BPM @ 2000 Psi. SI with 1400 Psi after 2 hr 10 rain 500 Psi. Flowed back 5 bbls diesel. Swabbed 15 bbls diesel, estimated 25 bb]s of water. Fluid level ~ 500', no gas. Water is 8.7# to 9.3~/, will check chlo- rides. I Pressures from DST ~15 IHP 1708, Flip 1700, IFP 270, FFP 516. SIP 0 516#, 10 rain 561#, 20 rain 595#, 3~ rain 619#, 40 rain 643#, 50 rain 655#, 60 rain 685#, 70 rain 706#, 80 rain 726#, 90 rain 740#, 100 rain 762#, 110 rain 777#, 126 rain CITIES SERVICE OIL COMP' 'Y w~. ... ly Well History- Interim Page 28 ........ - ~ ~"'" II II INSTRUCTIONS: Interim Reports shall'b® completed end submitted with the ~~.t ~' t~=~e~'~e~e,ertl ere .equi.ed fo. oll al. illin, may also be used f~ ~.cording daily work on significant wo, kovers. The description of~j~'~~ on Interim Reports should be o complete tepv. days Drilling Activity. Off s~gnificant wells the Tulsa Office may ~equest interim RlpOrtl ol'o Bhiet is tilled out. I. EASE / UFdlT NAME AND WEI,.L. NO. · , T.ewJ. s River ~o. I COUNT Y - P A R I SH - ST A T I:' - PRO V'INC Ir Kensi ~orough, AJsika ' DATE ^ND DEPTH 8/9/75 8/lO/75 8/11/75 8/12/75 FIEI. D OR PROSPECT NAME W~dcat i DESCRIPTION OF: WORK PERFORMED REGION Western &FIr NUMBER 9-0570011 96 days TIGHT HOLE ' ' DC: $30,283 CC: $2,856,096 · Present Operations: WOC Remarks.- Perf8 3,084-094'. ~ Ret 3;060t, 4-1/2 hrs. Swsb 120 bbls, est 25 bbls water per hr. 12,000 PFM, 8.6(/. 7'-1/2 hrl POOH, tubing plug with sand, se~t ret 3_~_~_~Q~l~ WIH, rig to squeeze. 1/2 hr squeeze 150 sks Class G 3/~-~2(16.1#)'. Final pressure 1200~ @ I BPM,. over displace 10 bbls. 4-3/4 hrs. WOC.. I hr pressure ~2 150 sks, 20 bbls KCL H 0 ahead (15.6#), Class G. Max 1400%, 2 BFM, drop to 9509, 1/4 BPM, overdisplaced 5 bbls water. 97 days TIGHT HOL~ DC: $42,890 CC: $2'898,986 Perfs 2,830-32', ret @ 2,824 Present Operations: WOC squeeze ~2 Remarks: 3 hr WOC, squeeze, perfs 3',084-094'. Load tubing 17 bbls, 57o KCL 'water, stung in-ret-, pump-in @ 3 BFM, '1800#. Mix squeeze ~3 150' sks Class G 16.2# per gal. Pump in 2500#, holding pressure, pump 128 sks-. in form, 10 ~ks in.casing. Blow rdt, reverse out 12 sks, POOH' perf 2=830-832's 2 per ft. Set ret @'2,824', WIH, load tubing 5% KCL water, pump. in @ 2 BPM @ 1900f~. Squeeze ~/1 150 sks Class G 15.3#, squeeze @ 1/4 BPM, max pressure !400(/, overdisplaced with 5 bb~s. water. PO ret, reverse out, WOC 7 hrs. Squeeze 92 load tubing 5% KCL water, sting in, pump in @ 300C~/, 2 BPM, mix squeeze out. 1/3 BPM, 1800Y:, overdisp!aced .5 bbls KCL water. PO ret, reverse out. WOC. · 98 days TIGHT HOLE' DC: $11,922 CC: $2,910,908 Retainer @ 2,774~ Present Operations: Drilling on retainer Remarks: WOC 6-3/4 hrs. Displaced KCL water, stab in ret 2,824', pressure 3200#, bled to 3,125(~ in 15 min. PO ret, stab in pressure to 3100#, dec to 305C~/ 20 min. PO ret, reverse out, POOH tubing rig and perf 2,790-92' (2 per fi). Set ret @ 2,774' , WIH with tubing, load tubing 57. KCL water, stab in ret, tnJ @ 2.5 BPM @ 1900#. No squeeze, 150 sks Class G 16.2Y/, squeeze to 2500~/, holding, 133 sks in form, 6 sks below ret, reverse out 1! sks, POOH, PU 8-1/2" HTC XZB, change rams. WOC 3:30 PM -3:30 AM (12 hfs). 99 days TIGHT HO~ PBTD: 2,824 t Present Operations: Running DST ~17 on tubing, perfs 2,804-8~Z' Remarks: Drill ret, no progress last 2 hfs 3-1/4 hrs. POOH for new bit 1-1/2 hrs. Drill ret 3-3/4 hrs. Drill cement 2,776-796' tag retr 2,824 3/4 hr. Cir. c hole 1/2 hr. Test squeeze perf 2,790-92' , held OK 1/2 hr. Pooh I-1/4 hr~ RLR and peri 7,~04-812' 4/[~ 32 hole~) ! hr. Chan§e rams ~o 2-7/8" 3//+ hr. W~ 2 hrs. .Rig test manifold, open tool, moderate blow to 12t! in 15 rain, GT$ 18 rain, 2' flare 1 hr. SI for buildup 2 hrs. Flow 2' flare, no chok~ PROCiVURf Rf~. ~.0. pressure 1/2 hr. $I 1 hr. Flow, no FP, flare decreasing 1/2 hr. Sl ~j:ily Well History- Interim Repor CIT S~SERVICE OIL COMPLY ~ ~ INSTRUCTIONS: Intm. im Reports shall ~ completed and submitted with th~..~.~.~ort for the Well. Interim ReportB o~e fequlred for oil drilling wells may ot.o be u,ed fo, re.eo,~ng doily wo, k ~ s,gnificont wo,kove, s. The de~~ ~ ~~n ~,~m Repo,I, ihould be doys Drilling Activity. On~igfllficant well, the Tulsa Office may,equest'lntmi~ Lewis River No. t ............................. ] Weste~ Kenai rou AtaSka .{ .itdeat { 9-057001t-i' DATE AND DEPTH DESCRIPTION'OF woRK PERFORMED ~: 2,780~ - Present OperatLons: ~a~ti~ on cement R~arks: 1-1/2 hfs SI DST #17. 1-1/2 hfs POOH with DST ~1'7. 4 hfs analysis B~ charts. 2 hrs W~. 1-1/4 hfs wai~ ~ perforators. 3/~ hr rig and set ret ~ 2,780'. 3/~ hr WIH with tubing to squeeze. 1/2 hr rig to squeeze. 1-1/2 hrs m~ and squeeze with 160 sks of slur~, staEe with 1350# and 1850', 3200#, displace 100 sks 10 sks below ret and rev ~t 50 sks. 1-1/2 hfs POOH. 8-3/4 hfs WOC. DST #~12 ' packer ~ 2,752' FIRST ~ SECO~ IH 1467# IF._ $86-2009 ISI' 229#. 278~ 333# 387# 517# ' 652# 892# 1007# 1157# 1245# 1286# 1295# 1303# 30 5mtn' 10 15 min. 20 rain 40"rain _50 60 70 80 90 rain_ 100' min' 110 mia. 120 mtn 140 mtn 209-219# 30 m~n 2nd SI 2~# 5 288~ 10 360# 20 406# 30 min' 561# 40 711# 50 rain - 868# 60 1017# 70 mim . 1203# 7 5 8/14/75 PROCEDURE REF, 123.0. 227-234# 30 mtn 3rd SI 278# 5 mtn 367# 10 mtn 473# 15 mtn 539# 20 mtn · 686# 30 843# 40 min 968# 50 min 1088# 60 1164# ' 70 Recovered 270' .water. lO1 d.%ys 'i ] 61{'£ P]J'I'D: 3,060t 1232# 80 1262# 90 mtn 1281# 100 1290# 110 1292# 120 1293# 150 1297# 180 1297# 240 1297# 403 Pct:.qent O(,eral:io,~s: Drilling on retaine£ Ca 3,060~ :'.,.,,turks: 14OC 1-1/2 hrs.~'Jlltng ~'c~ta{ner 3-3/4 hrn. i't~ol} 1 l,r. (~h:_n~o bit ~1 l~lll 1-1/4 l~:~. Co,.,l) drill rt~ia'll,,~r ,:.,d .'.0~ ,'...,,.nC Io ?,U24~, esr/mate I'o ?000#, OK 2-]/4 hrs. ]'t)Oll 3/4 l,r, ~.,tlh bit tt 51 1 hr. Drill r.talnor 2,824~ and c]~.~n r,ut t~ ],UbO' 4 1~'~. {'~.,{lIi with !3it l!~)l 1-]/2 1,~'~. k~lll with tit ~52 1 l~r. T,..,t '" c:rI'IE$ SERVIC:I: OIL ~O~P, .~ ' ?~i1~ W~II Hiuory- I,t~i~ R~o~ Page 30 ..~:~:~,:r~,~,,,,~... ,~ ~.~... ~.~ ~:~.:~.) · i ~-,~ ij~ ~ f:, :~ ~,,~ INSTRUCTIONS: · , ,'~ ~t C'~ ~ ~;~/, t..;;'. Interim ~epottl lhall be ~empleted end .ubmltted with the Final RepOrt far the Well. Inte~tm Reeeete e~e ~eeui~ed fat ell dHIlin may also be used fo~ recording daily work ~ significant wofkoverl. The description of work performed on Interim Reporte should be e complete report of days Drilling Activity. On significant wells the Tulsa Office may request Interim Reports os o sheet il filled out~ LEASE / UNIT NAME AND WEL.r NO. Lewis' River No. 1 COUNTY - PARISN-- STATE- PlqOV INC E. Kenai Boron Alaska DATE AND DEPTH 8/15/75 3,700 8/16/75 2,870 8/17/75 2,870 FIELD OR PROSPECT NAME Wildest DESCRIPTION OF WORK PERFORMED 8/18/75 3,700 'REGION Western 9-0570011-6 102 days TIGHT HOlE PBTD: 3,700' DC: $25,580 CC: $3,049,2&7 Present Operations: Waiting o~ cement Remarks.: Drilling cement 1-3/4 hrs. POOH 3/4 hr. RR 1/2 hr. with Bit (/53 1 hr. Drilling cement and tag retainer_~ 3_~~_60~test casing, 2000~/, would not hold 3-1/2 hrs. POOH'to check bit 1-1/4 hrs. WIH 1 hr, Drilling retainer to 3,950' 2-1/2 hrs. Circ hole 1 hr. POOH 1 hr. Rig go and set retainer @ 3,700 2 hrs. WIH to squeeze 1-1/4 hrs. Rig to squeeze 3/4 hr. Squeeze peris 3,717-22' , 150 SkS 16~f, standing pressure 1850~/, max pumping 2500#, annulus held OK 500~/ 1 hr. Reversed out 150 sks in formation, overdisplaced 5 bbla 1 hrs. Pull out retainer and WOC 3 hrs. · .. 103 days TIGHT HOLE .- PBTD: RTTS 2,870':' ': Present Operations:---~dai~ing on cement --- Remarks: 2 .hfs woc;'- 1-3/4 hrs test squeeze peris 3,717-25'.,' holding 2200#, reverse out. 1-3/4 hrs POOH. 1-1/~ hrs set retainer @ 3,629'. 1-1/2 hrs WIH. 2-1/2 hrs mix 150 sks class G cemen~' ~--- squeeze 3000#, holding 2500#, peris 3,647-51'. 1/4 hr reverse out. 1-1/~ hrs-POOH. 2'1/2 hrs WIH with RTTS tool,, set~ pressure annulus to'1000~/, bled to 600#, pressure tubing to 3000~, held OK. Peris 3,084-89'. . 1-1/4'hrs reset packer ~ 2,870', pressure annulus to ll0(W/, held OK. Pump in tubing 1-1/2 BPM, mix 100 sks' Class. G cement, squeeze peris ~ 3,084-89', to 2200f;', held 1500#, overalls- · placed 3 bbls. 3 hfs WO~. ' 'IC~ days TIGItT HOLE -. PBTD: RTTS 2,870' (peris 3,08~'-89~) Present Operations: Prep to drill cement Remarks: 6 hfs WOe. I hr test squeeze peris 3',084-89', 1600#. Pump in 3/4 BPH @ 300~t, squeeze 100 sks to 2400#, holding 2010#. 10 hrs. WOC. I hr pressure annulus 2000#, OK. 1-1/2 hfs POOH. 1/~ hr break do~n RTTS tools. 3/4 hr change rams. 2 hfs WIH with Bit #54, lIT: OSV3, serial t~E4728. 1/2 hr pressure to 2000~, 105 days TIGHT IIOLE PBTD: 3,700' (retainer) Cost: $3,095,123 Present Operations: Waiting on cement Remarks: D~rill_cement to 3,050' I hr. WIH t~_ _3_ ,_ 6_ ~2 9__~ (retainer) I hr. Dril~i~er ~___~3 6_~2_~7-3/4 hrs. POOH I hr. Change. bit and clean Junk sub 1/~ hr. WIH with Bit $~55 HTC O~VJ, serial $; EX632 I hr. r~lD~~~-r-~er_~', pressure casing to 2000/I, 'bled to 1300/~ in 15 ~in 1-1/4 hrs. CBU 3/4 hr. POOH 1 hr. Change.rams 1/~ hr. WIH with RTTS packer and ,set @ 3~467~ 1-1/2. hrs. Pressure up and inject 2000#, 3 BPM 1/2 hr. Squeeze perfs 3,647-51~ ~ith 170 sks Class G cement, 16t! max 2600#, holding 2100t/. Left 3 bbls in casing, packer PROCEDURE REF. 123.0. failed Q 3200//, reverse out, no cement 2 hrs. POOIt 1-1/2 hrs. WOC. CITIES' SERVICE OIL COMP~'~iY Page 31 Well History- Interim Roper i INSTRUCTIONS: Inie;.im Reports shol! be c'omrdeood and submitted with the*L~&:~i;~ort',~(6r may elsa be used fo, ,ecmding daily work ~ .ignif,Coflt wo, kovers. The 'des~r,p~G6~'¥f~w~k,.${j~~ I~&~ Reports should be · complete repot, of eech days Drilling Activity. On sigfllf,cont wells the Tulsa Of Joce may 'request Interim ReporJs ~;~.'~;~lj~ f611~ LEASE / UNIT NAME AND WELL NO. COUNT Y - PARIIN - STATE - PROVINCE Kenai gh Alaska DATE AND DEPTH 8/19/75 3,700 '106 days TIGHT. HOLE REGION Western Wildcat 9-0570011-4 DESCRIPTION OF woRK PERFORMED PBTD: 3,700* Present Operations: Pulling RTTS tool Remarks: WOC 5 hrs. WIH with Bit drill out to 3.700', test to 2000#, would not hold, start to pump in ~ ~~~P ~---~BPM @ 2000# 1-1/2 hrs. Circulate 1-1/2 hrs. POOH to squeeze 1-1/2 hrs. Change rams 1/2 hr. W-IH with RTTS 1-1/2 hrs. Squeeze peris @ 3,646', 51' with 170 sks 16#, max 2600#, holding @ 1800#, left 60' cement in casing. WOC 9 hrs. Pulling tubing 1 hr.' 8/20/75 7,320 107 days TIGHT HOLE - PBTD: ' 7,320* .- · . . · DC: $34,426 CC: $3,139,639 -- Present Operations: Prep to drill retainer @ &,320~ Remarks: 1-1/2 hfs POOH RTTS and change rams~ 1/4 hr breakdcn,,n RTTS. 1,1/4 hfs WIH with Bit #57 (rerun 55 and 56). 1/2 hr lay down 21 its DP. 1/2 hr complete trip in. 1-1/4 hrs drill cement 3,600' to 3,650', test peris 3,646-51' 1200# OK 3-1/4 hfs drill retainer @ 3,700' , · . 1-1/4 hrs POOH Bit #57. 1/2 hr clean junk .sub and change bits. 1 hr WIH with B'it #58 Smith SDGH, serial #CC727. 1-1/4 hfs comp..dri-ll to 3,760', test peris 3,717-22' to 1200# OK. 3 hrs drill cement and junk to 4,061'. 1-1/4 hrs POOH and change bits. 1 hr WIH with Bit #59 Smith SDGH, serial #NCC690. 1-3/4 hrs drilling retainer @'4,075". 1-3/4 hfs POOH Bit #59. I hr WIH with bit #60 (rerun ~55). 3/4 hr..;. cut drilling line. 1 hr complete GIH. 8/21/75 7,3.20 108 days TIGHT HOLE PBTD: 7,320* Cost: $3,152,120 Present Operations: POOH with-Bit ~62 Remarks: D~ill. retainer.4,320' 4 hrs. POOH 1-3/4 hrs. Change bl~ and clean junk su~~ W~'H with~bit #61 (rerun) 1-1/2 hrs. comp drilling retainer @ 4,320' 1/2 hrs. Run in hole to retainer @ 5,560' 1 hr. Drill retainer 5,560', push junk and d__ril~_~o~40'_ 2-1/2 hrs. CBU 3/4 hr. POOH 1-1/2 hrs. Clean junk sub 1/2 hr. WIH with HTC OCGJ, serial #ST701 1-3/4 hrs. Drill to retainer @ 5,640' 1-1/2. hrs. Drill to 5,696' 1-1/4 hrs. Circ out gas under retainer 1-1/4 hrs. C~-aS_out to .5~855~~_1 hr. CBU 1 hr. Start out of hole 1 hr. 8/22/75 7,320 109 days TIGHT HOLE P~TD: 7,320e Cost: $3,18~,013 Present Operations: Well SI to build pressure to attempt to flow load water Remarks: Ca~plete trip out hole 1-1/2 hrs. Change rams, lower flow line on drilling nipple and level rig, drillin~ nipple broken from Ily(lril 7-1/2 hrs. t~,]n RTTS on 2-7/8" 3000/~, held OK 3-3/4 hrs. Raise RTTS to 5,6.50', ctrc nl~d :;o.t packer, open well, dead 1/2 hr. Rig to ~wab I hr Sw,'~bbtug to 3,000~ fluid PROCEDURE REF. 123.0. i(-~t 2,400l on each tull, swab check valve cut out, unable Lo get ut.w uwnb due to fog at B(:]uga Air Strip, est gas 100 Mcfpd 8-3/4 hfs, Well '"CITIES 'SERVICE OIL COMP~'"~¥ ily Well History- Interim Report Pas. 32 SiP ! 5 I975 ' INSTRUCTIONS: Int'ef~m, Reports ,boll be completed ond submitted with the~l~,'.~[l~i~Or!'if.~r .~J~..~well,:~.Int~.t!~.?,porti of. ,equlre/for oll d, illtng wells md d~yl Drilling Activity. On significant wills thl lUllo Of~icl. moy rlqullt Interim Repor~i,b".. ~ ..... ~'i~&~ri.~ '!~ lill~ out, · · , LEASI~ ! UNIT NAME AND WEI.;L NO. Lewis River No. 1 COUNTY - PARISH-- ST ATE- PROVINCI~, Kena,i.. Bor, o,u~h~ Ala,s. ka DATE AND DEPTH 8/23/75 5,900 8/24/75 5,900 8/25/75 5,900 FIELD OR PROSPECT Nil, Il' Wildcat DESCRIPTION OF woRK PERFORMED REGION Western 9-057001.1-4, 110 days TIGHT HOLE PBTD: 5,900' :' . Present Operations: Prep to frac perfs @ 6,575-85', 5,707-15', 5,744- 52' 5,757-64' Attempting to clean well 7 hrs.. Swab 3 hfs Flowing 9 · ' to clean 6 hrs. SI 3/4 hr. TSIP 2260~. Flow 'on 3/4" choke 3-1/4 hrs. Rate 1692 Mcfpd, 315~ FTP SI 4 hfs, 2470~ SIT, P, 111 days TIGHT HOLE P BTD: 5,900 ' Present Operations: Testing peris 5,6?5-88' .5.,.707-15' 5,728-32' 5,736-52', 5,757-64', flowing to Clean after frae. Remarks: SI for buildup 1-1/4 hrs. Rig to frac 1-1/4 hrs. Frac, 6 BPM,'rnax .2700~t, rain 2200~, avg 2600~, instan~ SI 1900~, 2,000 §al pad, 2,000 gal with 1 PPG, 2,000 gag with 2 PPG, 2,000 ~al with 2 PPG, total sand 14,000~, total sand 14,000~I, total fluid 10,O00 gal. 150 ball- sealers 1-1/2 hrs. Swab 4 hfs to 5,500', well s~arted to flo~, flo~ to clean. ' ..... ' -. . ' . ' - - ---- . _- -. L ........ - _ -.- _ _-. - - 112 days TIGHT HOLE . '- '' . PBTD: 5 s 900 ~ _ · Present Operations: Circ to balance out wi. packer released 59650~ @ 7:30 I~o . . Remarks: 14-1/2 hrs flowing to clean after frae, rec 30 Bw ('~otal rec 110 bbls) 337 left to rec, no water last 4-1/2 hfs, FF rate 2238 'Mcfpd, 330~I FTP, 3/4" choke, separator 225 Psig, dif .55"', temp 94, orifice~ 1-3/4", 4" met'er run, rec fine sand and drill cuttings in flow li~e, 90% fora and 10% frac sand· '6 hrs SI. 0 rain 333# 26 rain 2000# 105 rain 2296# 1·25 rain 600# 33·50 rain 2100~ 120 rain 2306# 3.00 rain 800~) 40 rain 2153# 135 mtn 2315# 5.25 rain 1000# 45 mtn 2180~ 150 rain ' 2317# 7.6 rain 1200# 50 rain 2193Y~ 180 rain 2318# 10.3 rain 1400# 60 rain 2223# 210 mtn 2321# 14.8 rain 1600~ 70 rain 22420 240 rain ' 2322# 17.0 mia 1700# 80 rain 2260~ 300 rain 2323# 19.0 rain 1800~ 90 rain 2276(/ 360 rain 2323# 21.7 5 rain ' 1900# , 3-1/2 hfs unseat packer and circ out gas and condition hole. .. PROCEDURE REF. 123.0.19 SUBMIT ONE COMPLETED COPY TO E& P GENERAL OFFICE - TUL:~ rase 33 ! 075 ,' .... , INSTRUCTIONS: IflferiG~ Reports shall be'completed'and lubmltted with the Final Report for the Well. Interim Reports ore recoiled for ell drilling walls may also be u~ed for recording doily work ~ ,~gnificant workover~. The ~j~i~' ot~,~rfm~ o~,im Reportl ~hould be · complete report of e~ Lewfs River No. 1 ~estem FIELD OR PROSPECT NAME AFE NUMBER - ~ildcat , 9-0570011-6 COUNTY- PARISH- STATE- PROVINCE Ken,ai BOroui~ha Alaska DATE AND DEPTH 8/26/75 5,900 8/27/75 5,900 8/28/75 5,900 8/29/75 5,900 DESCRIPTION OF woRK PERFORMED 113 days TIGHT HOLE PBTD: 5,900" DC: $40,330 CC: $3,260,8~1 ' ~ Present Operations: GIH to peri 4,984-994~ Remarks: Circ hole 1/2 hr. POOH 5-1/2 hrs. Lay down RTTS tool 1/2 hr. Change pipe rams 1 hr. PU bit and GIH to 5,670', hit tight 1-1/2 hrs. Rotate with 6000#, some torque, PU max 20,000#, all other PU 5 to 1.O,000~ 3/4 hr. CBU, no steel recovery in samples 1/2 hr. POOH, bit pinched 1/2" below gage, 1/3 cup steel cuttings in Junk basket indicate casing partially collapsed 1-1/2 hrs. wa impression block 3 hrs. PU impression block and GIH, tight spot. 5,591', WIH to 5,670', 30,000~ wi, pull .loose @ 30,000# above, wi, pull. to 5,591' , 40,0004/ .wi over pull to pull thru 1-1/2 hrs. POOH with impression, 2 sides (opposite) 1/2" shaved off, 4 other spots show lead shaved off 1-1/2 hrs. wa perfora- tors 1-3/4 hrs. Peri 5,026-36'.. and 5,014-020', 4 per ft 4-1/2 hrs. GIH to perf. . . 114 days TIGHT HO!,E ...... . PBTD: 5900 ' --- · Present Operations: Laying down 2-7/8" tubing, work string · Remarks:Peris 3948-3 958' 4202-4210' 4278-4287' 4360-4364' 4730- 4738' 4984-4994' 5014-5020" 5026-5036' 5586-5600' 4 per ft on all , , -, , S . peris 6-1/2 hrs. Rig down perforators 1/2 hr. WIH, bit, casing scra- per to 5100' 1-1/2 hrs. Circ 1-1/2 hrs. Laydown DP and DC's 4-1/2 hr Change rams 1-1/2 hrs. Rig power tongs 1/2 hr. WIH with tubing to. 5600' 2 hrs. Circ I hr. Laying down 2-7/8" tubing 4-1/2 hrs. 115 days TIGHT HOLE PBTD: 5900 ' CoSt: $3,320,851 : Present Operations: Waiting on crossover sub on upper string Remarks: Complete laying down 2-7/8" work string 1/2 hr. Tally tubing rig tubing tongs and testers, WIH with tubing to 5557', top bottom packer ('single) 5079', top middle packer (single) 4433', top of upper packer (dual) 3890', test tubing to 5000#, lay down 3 hsd couplings and 1 bad Jr, start in hole with short string, crossover, would not pass thru hanger bowl, OD crossover 4-1/~",ID bowl 4-1/8" 22-1/2 hrs. Waiting on machine shop to turn crossover sub down to 4-1/16" 1 hr. 116 days TIGHT HOLE PBTD: 5900' Present Operations: Nip down BOP's Remarks: Waiting on crossover sub 3-1/2 hrs. PU and WIH with shaft airing 8-3/4 hrs. Pulling back pressure valve from long string 3/4 hr. Rig to displace CaC1 water from annulus 1 hr. Displacing annulus below bottom packer with oil, max 2 BFM, 310 bbls diesel 4-1/4 hrs. Drop balls to set packers 3/4 hr. Set packers 1 hr. Set back pres- sure valves in both strings 1 hr. Rig down BOP's 3 hrs. PROCEDURE REF. 123.0.19 SUBMIT ONE COMPLETED COPY TO E& P GENERAL OFFICE - TULSA . ~:ITIES SERVICE OIL COARPf~'~Y ~--~ , Daily Well History,-Interim Report Page 34 , , ,,, , , , ,, j . INSTRUCTIONS: Int~im Repe~e ~ell be ~emple~ed e~ ~ubmt.ed with the Final Repo~t ~er the well. Intedm Ree~e e~e eeeuired le~ ell aHIline ~ell~ ~ may olio be uued to~ recording daily work on lignificont workovers. The description of work perfmmed on Interim Repo~t8 0hould be o complete eepo~t of e~ days ~riJling Activity. On significant wells ~e Tulsa Office may request Interim Reports os o sheet ii filled out. '[."e,s',,'/'u~,'r NAMe ANO W£~:.~. NO. LeWt~ River No, l ,, COUNTY -- PARISH -- STAT ~ ' PROVINCE Kenai Borough, Alaska DATE A.ND DEPTH 8/30/75 5,900. IrleLD OR PROSPECT NAMe l'?ildcat 9-05 DESCRIPTION oF woRK PERFORMED ,11 Weate~ I Alre NUMBER 8/31/75 5,900 _1 117 days TIGHT ltOI~ PBTD: 5900 ' Present Operations: Flowing test, perf 5535-764e R~'narks: Nipple dmm BO?'s 6 'hrs. Install X-mas tree and test, held OK 3 hrs. Rig Otis and .pull valves from long string, attempt to pull valve from short string 3-1/4 hrs. Swab long string to 3500', well kicked .off 5-3/4 hrs, Flow thru 1" choke to clean, turn thru separatm on 3/4" choke, FTP 475~, rate 2515 Mcfpd. 118 days TIGHT tlOT.~- PBTD: 5900" Present Operations: Working wireline tools Remarks: Flow lower zone on 1/2" choke 1 hr. WIH to set tubing plug @ 5091' work thru sliding sleeve @ 4447' plug set @ 4447' 3-3/4 hrs. Wait on fishing tool .7-1/4 hrs. WIH and rec plug, WIH with new plug, plug set @ 4447', fish plug. WIH with new plug, work thru @ 4447', presently-working plug thru sliding sleeve @ 50?fo : _ PROCEDURE REF. 123,0.19 SUBMIT ONE COMPLETED COPY TO E& P GENERAL OFFICE - TULSA Depth Perf. 7725'-- 7730' T=128°F 7725'- 7730' T=130°F CONFIDENTIAL lst..Open 2nd Open] ,: Initial P- Initial/P+.!i Final P/Time ISIP Final P/Time · IHP 3988 2632v2632/20min .3148/1 2652-2632/45Min 3000/2hr. Diesel Cushion hr. DRILL STEM TESTS - LEWIS RIVER A-1 3rd Open Initial P- 2nd SIP ' Final P/Time 3rd SIP 3988 49-49/15min 2 psi on closed DP 197/1 49-74~2~ hrS, ,. No SIP hr. very weak lblow died in 20 min. 4th Open Initial P- Final P/Time 5th Open Initial P- 4th SIP Final P/Time 5th SIP FHp ' 3988 3988 6097'- 6102' 5707'- 5715' 5707'- · 5707'- 5715' Open. 6 hrs. 5 hr.47 min., weak'~ increas- ing blow / 137-/5 min moderate blow ----- 8'66-/5 min GTS '2 ,in 630 Psi on¼'~ chk in 5 ,, 2969 93-82/4 hfs 2969 weak blow -/4hfs --- 335/1 hr 152-158/6hfs~ 630/4% hrs. --- moderate btqw Rec' d 320' GTS 1 ~,7~5!,,hr ~I brine est 850 cfpd 2483/thr 421-423/~.2~mtn 2690/4 hr. --- S4' O~ ~" ' bled tbg 15 p .*~i. '*~i"*,:i ~ to 50psi chk,gas.lbUbbles duringSI in annulus --tm, 1185/ Rec'd 90' brine --'- .................... 2978 259 min . Broke Pm. w/diesel and surfactant at 3800 psi, pump in at 3400 to 2800, shut in, decline to 2000 psi in 3 hfs -swab tbg to 5300' no fluid rise Flow:for cleanup for 23.5 hr. Test Rates: 2698/ 24 hr- 38 min. 5675' .... 5685' 5'744'- 5752' 5757'- mcf psi 5764' #1: 1692- 461/23.5 hr 5707'- #2: 414-2379/11 hr 5715' #3: 843-2026/4.25 hr #4 1310-1331/4.25 hr 1st .Open Depth Initial P- Perf. IHP Final P/Time 5576'- 2905 70-113/2 hfs 5586' '55'- 2876 -J45' { 62-62/- 4364'- 2256 -/2<hfs 4369' 5-10 mcfpd 5535'- 5545' 4096'- 2105 4116' -/ I hr. ,17'- 1900 180:173/ 3725' 3647'- 165-276/35 3651' min. 3717'- 3725' DRILL STEM TESTS - LEWIS RIVER A-1 continued 2nd Open'~ , Initial ISIP Final P/Time 2nd SIP a,.! 2671/4hr Initia~ :Flow 2676/24 hr 762/4~ih~,~ Test Ra~es: mcf-PS$ #1': 2290-2875/4 hr #2: 642-2341/4 hr #3:1440-1946/4 hr #4 1930-1655/4 hr wea~ b~ow ,- /4 hfs Opene~%0~h~s 2154/ flo~l.~n¢~ea~ing 7 hrs. to ~10:;.Mcfpd, 18 .ins. B~, 351 - /2 hr floWn~o~i~cleanup 2018/ 388 ~m~e.~,~ ~ 25hrs. Test R~es: 12mtn. mcf '.,.. Psi,, ~ 2314~:.582/~05 min #2 474r1763/4 hfs #3 ~237~Z~6~/~ hfs #4 ~696-1186/4 hfs 952/ 259-259/- 2~ hfs ~716 2hr. 264-273/T}'60. 7.in min. 1543/ 5-3/4 hr 3rd Open Initial P- Final P/Time 62-62/- 522 Mcfpd in 3 hrs. 372/ 5hfs --- I8min 1714/4hrs 286-357/- 32min 3rd SIP 848/1% hr 1670/2hfs 19min 4th Open Initial P- Final P/Time 365-200/- 4th SIP 1627/3 hr 29min 5th Open Initial P- Final P/Time 286/- 5th SIP FHP --- 2276 ___ 2097 1919 1631/4hfs 1834 26,in DRILL STEM TESTS - LEWIS RIVER A-1 .continued ' 1st Open 2nd 0pant, ~epth Initial P- Initial,P.,-~l ~, Perf. IHP Final ~/Time ISIP Final P/Time A 3647'- --- flow for cleanup. /40 min MCF /?!me 3651' ' 272 . /25 win 3717'- 281 /70 mtn 3725' ~ ,5~084, 3094' 1708 270-516/60min 803/126 min 478~47~,/,,,' no blow 3rd Open Initial P- 2nd SIP Final P/Time 3rd SIP , /70 min MCF /Time 306 /25 min 305 /50 min 4th Open Initial P- Final P/Time 4th SIP 5th Open Initial ~- Final' P/Tiwe /150 min MCF 305 5th SIP /Time Acidized max MCF /Time ,, ~ /20 min Rate 5 BPM at 342 /3 hr 2700 psi, 30 min Flowed backl5 340 : /3 hr Bbls - died, 50 win swabbed 5Bbls 375 /4 hr diesel - well 20 win began flow 375 /5 hr 10 win CALCULAT!.eN OF~TTOHHI~LE PRESSURE FROH WF~4~HEAD' PRESSUR£ /'" ,~ GAS & GAS-CONDENSATE .. LEWIS RI VER ZeNE I · kIELLSTREAH GRAVITY = 0.555 (AIR=I.O) .- CRITICAL PRESS· = 67E PSIA CRITICAL TEHP, = 34~ DEG RANK~[E BeTTOHHlaLE PRESSURES AT 5575 FT'(HD) TVD m 5575 FT . ATM~SPHERXC PRESSURE = 14,65 PS~G . ~LHEAD TEMP, = 55 *D'EG F. BaTT~MH~LE TEMP, .= i07 '. . , _ , . ' * *- * ,'~ * I ~ .. .._ DATE SEPT23 HRSLSHUTIN klHP-PSZG BHS!P-PSI'A PSI/FTCMD) . Z' FACTOR lO-O0'O * P-3EO. - 2666 ,059' ,8466 . LEWIS RIVER ZONE 2 ~ · , . t~ELLSTREAH_ GRAVITY.= 0,555 CAiR=I·O) -. ,, ' ,- CRITICAL PRESS. = 67~> PSI-A.,. ·CRITICAL TEHP- '= 34E DE~ RANKINE ~TTBHHOLE PRESSURES .AT 4100 FT'(MD) T~D = 4100 FT ATMOSPHERIC PRESSURE =-' 14.65 .PSIG · -,. .- ~LLH~AD T~.' = 55' DEG F ~ B~TT~HH~LE TE~ · = 89. ~.,. *~ ~ - . DATE HRS~'SHUT~N '~P-Ps~G 'BHS~,P~PS~A' PS~/FT(~D) Z FACTOR SEpT 28 720.000. 183~ ' 2037 ' .047 .8277 -_ CALCULATION OF BOTTeHHOLE PRESSURE,-FROH. WELLHEAD PRESSURE FOR GAS & GAS-CONDENSATE WELLS- . 1 LEWIS RIVER ZONE I _- . . .' laELLSTREAM GRAVITY = 0·555 (AIR=t.O) ' - , ' ' ~- CRITICAL PRESS, = 672'PSIA CRITICAL 'TEHP. = 342.DEG RANKINE B~TTOMHOLE PRESSURES'AT 5575. FI*' (MD) TVD = 5575 FI ATHOSPHERIc PRESSURE = 14.65' PSIG ' ' ' .... I[LOW STRING I.D. = 2',44 .INCHES · · . .. i ~ ~1 ~ .. NELLHEAD TEMP' '= 55 DEG 'F BOTTOMHOLE TEMP. = 107 DATE ' SEPT23 ~gpT23 SEPT23 - i ! t~ - . ,,HAS- FLeWI NG RATE-HCFPD WHP-.PSIG BHFP-PSI A PSI/FT(ND) · 000 I 644 1930 2223 . 050 -500 220~- . I?P5 1991' .045 · 750 2540, ' ! 540 1782 -041 -500 3107 1215 1419 , .034 LEIglS .RIVER .ZONE 2 WELLSTREAt4 .GRAVITY = 0,555' (A~R=I,O) .--. '..":~- · CRITICAL PRESS''=, 672 PSIA CRITICAL TEHP. = 342 DEG RANKINE BlaTTOMHOLE PRESSURES AT 4100 FT' (MD) :{VD = 4100 FI .. " ATMOSPHERIC. PRESSURE = 14·65 PSiG FLeW STRING I,D. = '2,44 II~CHES . . . t~ELLHEAD TEHP. = 55 DEG F BOTTOHHOLE TEHP. = 89 ! f! - DATE ' SEPT2 6 SEPT2 & SEPT26 HRS-FLOWING RATE-MCFPD WHP-..PSI.G .BHFP-PSIA PSI/FTCMI~) 2aO00 I 621 I 615 1801 .042 2-000. 2146 i.495 I 670 ,039 · 750 2522 12 65 1418 .034 10 9 8 2 3 4 5 10 6 4 2 3. 4 5 6 7 8 9 10 10 9. 8 2 3 4 6 3 2 3. 4 5 6 7 8 9 10 CitieG $er~;co 0il Compl. ~ Well: I~wis River #i-A Section 2- T1;i i{- RQW Northern Cook Inlet ~sin Completion Tubin~ - Ix)n~ StrinG NOTEs Long erring ran in hole' on 8-a7-75. ~a lo~J hiring wt. wao 34,000// in 10.0 PPG CaC19 water· Ail o£ the tubing.and~ tubing Pup Jts. were 2-7/8" OD 6.5 ~//~t N-80 with EUE 8RD thrcado. U. ed 2100 £t/lb torque on makeup. Ail of the tubing couplings were externally tested to 5000 PSI. ' . Zero Point: RKB (20 ft, above G~) -- 15.43 ft. above the top f.lange of the 1--6m 5000 x 12" 5000 PSI tubing head spool. Item .. · ". No-- . Description. "Length. ~ . .Bottom , e : . 'Depth below zero ~pt. (RKB) 15.~3 0 15.~3 I McEvoy Dual Tubing Hanger 1. O0 15.43 16.43 1 J~. 2-7/8" tubing' (collar down) 31.24 16.43 47.67 .1 Double pin 2-7/8" EUE 8RD thd. .65 47.67 48.32 t 1 122 Jtso · ~ . ee 1. Pup Jt. 2-7/8': Tubing Pup Jr. · - 2-7/8" Tubing Pup Jr. 2-7/8" Tubing Pup Jt. ' 2-7/8 Tubing X-O Sub, 2-7/8 EU~ 8RD Box x 3!a EUE 'lORD-Box, b~" OD 9-~/8 B~er Model A-~ Du~l H~ro- s~atic Retrievable Packer with A 3.5o" Bore, ~C, ooo ~ 3!" 'X-O sub, ~ EUE 10RD Box X 2-7/8 zu~ 8RD mn aown 4¼" o~ Otis .I~pe X-landing nipple 3~" OD x 2.313''~ ID. '2-7/8' tubin~ . 2-7/8" tubing Pup Jr. Blast ~oint 3.688" OD x 2.~i"ID · . Blast joint 3. 688" OD x 2.b~l"ID · 2-7/8" tubing Blast joint 3. 688" OD x 2.bbl"ID Blast joint 3. 688" OD x 2.~i"ID 2-7/8" Tubing Pup Jr. 2-7/8" Tubing Blast joint 3.688" OD x 2.b~l"ID Blast joint 3.688" OD x 2.b41"ID 2-7/8" Tubing Pup J~. 2-7/8" Tubing 2-?/8" Jr. · o 1 Jr. 1 1 1 5 Jts. 1 1 1 2 Jts. 1 1 1 1 Jr. 1 t 'e 4.17 ~8.32 52.49 8.13 52. h9 60.62' 10.20 60.62 70.82 3818.58 . 70.82 3889.40 · 70 3889.4o · 3890.10 zz. 7 3 90. 0 .50 3901.67 3902.17 31.52 ;.,.. o8 20.30 lO.05 123.26 · 19.90 19.90 ~. :l", 61.19 19.92 10.06 . 10.21 32. ~9 ~ 3903.17 3903.17 .' 3934.69 3934.69 3938.77 3938.77 3959.07" 3959. o? 3969.12 3969.12 ~o92.38 4092.38 .. 4112.28 ;4.112.28 "' 4132.18 4132..18 4136.29 413o.29 ~197.48 4197.~8 ~217.~0 ~217.40 4227.46 4227.46 4237.67 4237.67 4270.26 4270.26 4274.39 Citics Scrvico ~%~Company ]~wiu River //1 Comp3ction Tubing - Long String cont. Itcm 1 2 J%S o 1' 1 1 Jr. 1 . 9 Jts. 1 1 · 7 Jts. 1 1 1 1 1 Jr. '1 i. 14 Jts. 1 1 D.~scription~ __ Blast ~oint S.688"0D x 2.~41"ID a-7/O" Tubing Blast joint 3.688"0D x 2.1~41"ID Blast joint 3.688"0D x 2.441"ID 2-7/8" ~b~ O~is, ~e X-O slidi~ slee~; 3-3/~"OD ~~D 2-7/8" robing ~ Jr. Cross-over cplg; 2-7/8" E~ 8~ x 9-~/8 B~er Model Ht Single .string, doyle grip ~ostatic rie vab~ke r, ~0,00~ '. hear, 3" b~ Cross-o~r cplg; B'} E~ 10~ B. x 2-7/~" E~ 8~ P.; ~" O~ 2-7/8" ~bi~ ~ Jr. Otis ~e x~l~di~ nipple; 3L3/~". OD x 2.3~3~ " Blas~ ~oin% '3.~8"0D x ~.~i"ID 2-7/8" ~bi~ ~p Join% ~-7/8" ~binz . 2-7/8" ~bin~ ~ J%. Blas~ ~oin~ 3.~8"0D x Z~4~i"ID Blas% ~oin% 3.6~"OD x ~.~I"ID Blas% ~oin~ 3. ~8"OD x R.~i"ID 2-7/8" ~%in~ O%is X-O Slidi~ Slee~ 3-3/~"0D x ~. 313"ID~ ~-7/8" ~%i~ ~ JO. Cross-over sub~ 2-7/8 E~ 8~ B. x 3~" E~ ~o~ B. ~,x" o~ 9-~/8" B~er Model "~" sidle double ~rip ~osta%ic re%rievable packer~ ~0~00~ shear, 3" Bore Cross-over sub~ 3~ E~ 10~ B. x ~-7/8 E~ 8~ Pin~ =~ OD z-?/8" ~%i~ ~ O~is "X" L~din~ nipple~ 3~~ x 2. 313" ID Blas~ ~oin~ 3.~"OD x 2.~i"ID O~is "X" ~ndi~ ni~le~ 3-3/~"0D x ~. 313" ~ ~-7/8 ~%in~ ~p J~. B~er ~11 sea~ shear ou~ sub ~ ~o~,tt0~ 20.30 h~74.39 63.03 ~29~.69 .4358.52 . 20.~6. h358.62 h378.98 lO.17. 4378.98 ~389.15 31.78 4389.15 4~2o.93 · 3.15 ~ hh24.o8' 8.22 4424.o8 q432,3o ,?2 4q32.3o q433.o2 · .5O 6.08 278.60 20.30 6.05 218.46 8.1o 20.21 20.28 20.30 31.25 3.10 4.21 .72 7. O0 · 50 ~.16 1.02 4433.02 4440.02 4440.02 4440.52 4440.52 4446.60 60 ~F~47.60 4726.2O 4726.20 4746.50 4752.55' 4971.01 ~979.11 4999.32 5o~9.6o 5039.90 5o71:15 · ~ 4746.50 4752.55 4971.01 4979.11 4999.3~ · ' 5019.60 5039.90 5071.15 5074.25 5074.25 5078.46 5078.46 5079.18' 5079.18 5086.18 5086.18 ' 5086; 68 5086. ~8 5090.84 5o90.8~ 5091.86 438.48' 5o91.86 5530.34 20.29 553o.34 5550.63 1.O0 5550.63 5551.63 · 4.!6 5551.63 5555.79 ,59 5555.79 5556.38 CONFIDENTIAL CORE LABORATORIES, INC. BALLASt TEXAS 75~47 June 30, 1975 Cities Service Oil Company 900 Colorado State Bank Building 1600 Broadway Denver, Colorado 80202 Attention: Mr. B. L. Tompson Subject: Core-Analysis Data Lewis'River #1 W/C Fi eld -Mat-Su County, Alaska Gentlemen: PercuSsion type sTdewall core samples recove red from the subject well were submitted to our Anchorage laboratory £or analysis. The results o£ these analyses are presented in the accompanying report with a general lithological description oF the samples. These cores were submitted t:or permeability, porosity and fluid saturation determinations. We sincerely appreciate this opportunTty to serve you and trust we will be called on again in the future. Very truly yours, JAC:sme CORE LABORATORIES· INC,, District Manager i~., CaliFornia Prot:esslonal EngineeCL?j Reg. No. P-1176 AUSTIqA I. IA ASIA CONFIDENTIAl, CORE: LALIORATORIE$. INC. Petroleum Rcscn,0ir Engincedn£ DALLAS, TEXAS CORE ANALYSIS RESULTS PaRe N,,,_ Cities Service 011 Co' Com.?any ......... Wcll Lewis River '~ 1 Field: W/C Cou,,t7 ..... Mot- Su State_OJ_O.S.__ka Formation Core Type $i dewa i i Drilling Fluid__ .... Elev ....... Location File, qP-37_.353 Date ]',e?ort_ ~,/_2L~.5_ ......... ViJGG¥ · VGV Analysts_ __~.$ P_ ..... I'NAC?UNII~ · tNAC NL IC~)I?LY. ~1./ LAMINA rlON - LAM ¥.r#y. ¥// I?¥/OLITIC..117¥ W~'I'N , w/ Lithological Abbreviations 8ANDY - ('DY tiNg · tN CR¥1ITALLINg LIMY · LMY COANII · CIg G~ANULAN POROSITY Pr R Cli;l~;T PORI~ 9AMPLE DEICRIIITION AND REMANKE -Max. S0.% Stw% 1 3 4 5 6 "7' ! 8 9 '10 11 12 13 15 16 17 ]9 20 21 22 23 24 25 26 27 5030 5579 5684 5747 5935 .5943 6120 5582 5585 5588 5591 5673 5677 5707 5745 5902 5968 5972 6092 6094 61.04 7160 7413 7620 7730 7873 7890 2.9 7.5 16.0 60.0 133.0 57.0 210.0 2.8 '18.0 3.2 12 14 22 16 0.3 8.4 13 36 '75 4.8 9O 282 8.9 13 17 24 23 17.8~ 0.0 20.1 ~ 0.0 17.0~ 0.0 20.7~ 0.0 23.6 3.0 20.7 0o0 12.2 0.0 ' 23.1~ 3.0 23.0/ 2.9 20.2~ 0.0 21.7,~ 0.0 27.5 0.0 20.2/ 0.0 21.6~/ '0.0 11.8 ~0.0 5.o .i J o.o 19.9 v'02.4 24.6 0.0 25.0 0.0 18.1 0.0 26.1 0.0 24.5 1.5 18.9 0.0 19.2 0.0 21.3 0.0 23.6 0.0 24.3 0.0 74.3 60.4 60.8 57.4 59.4 59.8 53.2 72.2 59,4 61.4 65.2 45.1 58.3 · 61.8 73.7 6O.4 61.2 71.6 66.9 62.7 75.0 63.2 70.7 63.4 54.3 71.3 62.5 ss, v Fg-v slty, no Flu ss, vf-fg, slty ss, vf-Fg, slty ss, f-mg, cly ss, fg, cly same os above ss, f'g, carblame ss, uF-Fg, slty ss, v F-rog, clarb lam, s[ty same os above ss, vF-fg, cly, slty same os above same as above, corb lam same as above si tst ss, vFg, slty, sc carb cong., tr, Flu, yellow ss, v~-f'g, cly ss, £-mg, cly same as above same as above ss, vF-Fg, cly, carb lam ss, vF-f'g, cly ss, F-rog, cly ss, vF-fg, cly ss, vF-Fg, cly ss, m-cg, cly 'rhrse ~,ltiiJv~.e% ~,j,llj~irl% Or illte~J,~el.tlitln~ ale b~e,I on observati(m, and materials supIH~ed by the clienl CONFIDENTIAL C~ticn '~ ' . ,,_ry.,ce 0il Company lewis Riwr Section 2- Nort}~crn Cook Inlet Basin Completion Tubing - Short Strings' NOTE: Short string ran in hole on 8-28-75. Short string wi' was 18,000 ~ in lO.O PPG CaC12 water. Slacked off 15,000 ~/ of tubing wt. on Baker ' seal nipple in dual packer. All tubing couplings were externally tested to 5000 PSI after makeup. All of the tubing was 2-7/8" OD 6, 5 ~/ft. N-80 with EUE 8RD threads and beveled couplings except the Pup Jts. which were J-55 with EUE 8RD threads and beveled cplgs. ~]]c N-80 cplgs, were torqued to 2100 ft-lb makeup and the J-55 cplgs, were torqued to 1600 ft-lb ma]%eup. Zero Point: Rotaz-y Kelly Bushing - 20 ft. above G.L. - OR 15.43 ft. above top flange of 12" 5000 x 10" 5000 PSI tbg. hd. spool. Item No~ _Des cripti.0n~ ' ~ Top~ Bottom 1.50 15.43 '1 leO0 1 Jr. 31.75 I 0.65 . i 10,07 1 10. ll 121 Jts. ' 3798.79 ~ 3.15 Slack off 'wt. on seal nipple Depth below zero pt. McEvoy Tubing Hanger 2-7/8 tubing w/cplg on- btm. Double pin sub w/EUE 8RD thd. 2-"¢/8 tbg. Pup Jt. ' 2-7/8 tbg. Pup Jr. · 2-7/8 tbg. Pu~ Jr. 2-7/8 tubing Otis X-O sliding sleeve; 3-3/4" OD 'x 2.313" ID ~ z-?/8 t~g. Pup Jr. Cross-over sub 4" OD Baker snap latch seal assembly for A-5 PKR All completion detail listed below is retrievable with long string Baker Model An-5 dual pkr (.short string profile) 2.313"_vD. ~ .~ 2-7/8 tbg. Pup Jt. Baker "D" Hydro-Trip Pressure sub 10.05 .49 8.13 7.97 1.00 ~.].o 1.5o o 15.~3 15.43 16.43 16.43 48.18 h8.18 ~8.83 48.83 52.91 52' 91 62.98 62.98 73.09 73.09 3871.88 3871.88 3875.03 3875.o3 3885.08 3885.08 3885.57 3885.57 3893.70 3893.70 39Ol.67 39ol.67 39o2~67 3902.6? 39o6.77 3906.77 3908.27' Ir i Ticket FLUID SAMPLE DATA Date 8-12-75 Number 607831 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job OPEN HOLE District ANCHORAGE cc. oi~ MR. GENTRY cc. Water Tester MR. LYONS Witness MR. HARMON cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY DR S Gravity ° APl @ °F. EQU I PM ENT & H aLE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDE Elevation ~)8 m Ft, CONTENT -- Net Productive Interval 2804-2812' Ft, Recovery Water ~ @ °F. ppm All Depths Measured From Kal 1 v Bushing 20' Recovery Mud ~ @~ °F.- ppm Total Depth 3084~ - Ft. Recovery Mud Filtrate ~ @~ °F. ppm Main Hole/Casing Size 9 5/8 47# , Mud Pit Sample .... @ ~F. ppm Drill Collar Length 188' 4.... 2 7/16" Mud Pit Sample Filtrate~ @~°F. ppm Drill Pipe Length 2534-i I.D. .3.. 826"._' Packer Depth(s)2752' ~ _ Ft Mud Weight vis cp Depth Tester Valve2534' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke 1 / 4- 3 / 4" Choke 3 / 4" -- Recovered Feet of Recovered Feet of 1 Recovered Feet of Recovered Feet of Recovered Feet of · Remarks Opened tool for 56 minute first flow with a very strong blow. 6# PSI in 5 minutes, still closed in at surface. Closed tool for 123 minute first closed .in pressure. Reopened tool for 33 minute second flow on 3/4" choke, gas to surface 20 50. Closed tool for 63 minute second closed in pressure. Reopenedtool for 19 minute third flow with a light blow. Closed tool for 299 minute third closed in pressure. (Had a l iqht blow on S~¢0rld flow) Gauge No. 753 Gauge No. 489 Gauge No. TEMPERATURE TIME Depth: 2741 Ft. Depth: 2768 Ft. Depth: Ft. 72 HourClock 72HourCIock Hour Clock Tool A.M. Est. °F. BlankedOff No BlankedoffYes BlankedOff Opened 20' 2771 ' Opened A.M. __Actuo~ 77 'F. Pressures , Pressures Pressures Bypass (~: 30 , P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic 1448 1467 1462 Minutes Minutes *-~o Flow Initial 208 ! 186 220 ~,~ ... Final 184 200 197 61 56 Closed in 1285 1303 1297 117 123 'o.a Initial 194 209 207 CO o~.r. Flow Final ~- 206 219 219 35 33 Creased in 1264 2176 1276 60 63 ~ Flow Initial 211 227 222 ~ Final 221 234 233 20 l 9 OOS.d i. 1283 1 287 1295 300 2991 -- Final Hydrostatic 1448 1457 1462 FORM 'IUI-RI--PRINTED IN U,'I~,A. FORMATION TEST DATA LITYL~"B ge~71 lam e/74 ~ Gauge ..~o. ,, First Flow Period Time Deft. .000' .000 .0068 .01 80 .0293 · 0405 .0518 .0630 PSIG Temp. Corr. 208 199' 170 170 174 178 184 753 J Depth First Closed In Pressure Time Defl. .000" · 000 .0154 .0274 .0395 .0516 .0636 .0757 .0878 ·0999 .1119 L t+8 o~-.~- PSIG Temp. Corr. 184 384** 570 774 996 1163 1248 1278 1283 27.141' Second Flow Period Time Defl. .000" .000 · 0097 .0158 .0218 .0279 .0339 .0400 PSIG Temp. Corr. 194 196*** 199 201 203 205 206 Clock No. 10394 Second Closed In Pressure Time Deft. .000" · 000 ·0096 .0159 .0223 .0287 .0351 .0415 .0479 .0542 1285 .0606 .1240 1285 .0670 P$1G Temp. Corr. 206 327-**~ 43O 564 692 854 985 1089 1199 1263 I JTicket 72 hou. r, No. Third Flow Period Time Deft. .000" · 000 · 0051 .0088 .0126 .0164 .0202 .0240 PSIG Temo. Corr. 211 213*** 216 218 I I 219 221 · 22! 607831 ...... j Closed In Pressure Time Deft. .000" .000 .0210 · ..0432 .,0653 .0875 · 1096 .1317 .1539 I I .1760 ,1982 .2203 ,2424 ,2646 .... ,2867 ,3089 ~3310 LooZ P$1G TemD. Corr. 221 , gauge No. o .000 2' 0066 ,0177 i.0288 .0399 .0509 1.0620 I1 '3I 14 15 Readin~l ,llnte~al 489 Depth 2768' Clock No. _ 220 .000 197 .000 207 .000 206* 185 183 187 .0155 .0276 .0398 .0520 192 .0642 197 lO .0763 · 0885 373** 560 762 983 .0087 .0142 .0196 .0251 209t.* 212 241 217 REMARKS: · 0099 .0164 .0230 hour 72,, · 0296 1154 .0305 218 .0361 219 1247 1291 .0360 .0427 .0493 219 358,*~ 468 596 .. 730 871 990 ,, 1095 · 1007 1297 .0559 1208 · 1129 1297 .0624 1252 1297 .0690 .1250 11 6minutes ****-9 minutes *****-4 minutes ******-19 minutes· * First intervalequal to 1276. .000 ~ .0044. .0077 .0111 ! ,0144. ,0177 ,0210 222 228*** 229 232 233. .. 233 233 **-14 minutes .... Only 113 mi.nutes segmented ,00o ~*, 0210 .0431 .o652 ,0873 · 1094 .1315 · 1536 .1757 .1978 .2]99 .2420 ,2641 ,2862 ,3083 .3300 ***-8 mi nutes 1029 i 1211 J 1278 1292 I 1293 1295 1295 1295 1295 1295 1295 1295 1295 1295 20 Minute~ FORM I$3-RI--PRINT~:D IN U.S.A. ,, SPECIAL PRESSURE DATA L, ITTL. Ir'$ ii6573 75C $/74 Drill Pipe or Tubing ................ Reversing Sub ...................... i: Water Cushion Valve ................ Drill Pipe ........................ 4,50" Drill Collars ...................... 6,25" Handling Sub & Choke Assembly ...... Dual CIP Valve ................... ~" Dual CIP Sampler .................. Hydro-Spring Tester ................ 5" .3,826" 2 7/16" t88" .75" .87" 3.00" 1.75" 1.00" 2.44" 2.44" Multiple CIP Sampler ............... Extension Joint .................... 5" AP Running Case .................. 5" Hydraulic Jar ..................... 5" VR Safety Joint ................... 5" Pressure Equalizing Crossover ......... Packer Assembly ... ]~$. .......... 8.20" ~. ?e. rfs ................. 2.78" Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... 3 7/8" ~-.SO0..Temp. - 3 7/8" Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... FORM 187.Rl~PRINT~'D IN U.B.A. EC~UIPMENT DATA TIC~ NO. 607851 LENGTH DEPTH 2534' 188' 4,89' 8.47' 7.18' 4.05' . 5,06' 3,52' 2534 ' 4.59' 8.80' 4.09' 1.06' 2741' 2752' 2768' 2771' 3084 ' LITTLE'B; Ps Q Q~ R r~ 1o T Z OF3 --- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF4 ~--- Theoretical Open Flow Potential with/Damage Removed Min .... MCF/D -'~ Extrapolated Static Pressure ............................... Psig. -~ Final Flow Pressure . Psig. -- Potentiometric Surface (Fresh Water') ...................... Feet ' -'- Average Adjusted Production Rate During Test ................ bbls/day --- Theoretical Production w/Damage Removed .................. bbls/day m Measured Gas Production Rate ............................ MCF/D -- Corrected Recovery ...................................... bbls Radius of Well Bore ...................................... Feet ~- Flow Time ............................................. Minutes ~ Total Flow Time ...................... Minutes Temperature Rankine .................................... °R -- Compressibility Factor .................................... ~U -- Viscosity Gas or Liquid ................................... CP Log Common Log * Pofentiometric Surfi~ce Refi~,-:,nce to Rof~.y T~Io When Elev,'~tion Not Given, Fresh Water CorrectecJ to log F. Each Horizontal Line Equal to 1000 p.s.i. F L U i D S A M P L E D A T A Ticket ~' Date 7-14-75 Number 607910 ' Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE ~o cc. Oil · cc. Water Tester MR. BOATMAN Witness MR. CLENDENIN cc. Mud Drilling I Tot. Liquid cc. ContractorBRINKERHOFF DRILLING COMPANY DR $ Gravity ° APl @ °F. E Q U I P M E N T & H O L E D A T ^ Gas/Oil Ratio cu. ft./bbl. Formation Tested - , RESISTIVITY CHLORIDE Elevation 98 m Ft. CONTENT Net Productive Interval 7725- 7730' Ft. Recovery Water ~ @ ~ °F. ppm All Depths Measured From Kelly Bushing 20' Recovery Mud ~ @~°F. ppm Total Depth 7795' RBP Ft. Recovery Mud Filtrate __ @ __ °F. ppm Main Hole/Casing Size 9 5/8. 47# Mud Pit Sample @ °F. ppm Drill Collar Length - I.D. - Mud Pit Sample Filtrate @~°F. ppm Drill Pipe Length 7659' I.D. 3.826" Packer Depth(s) 7677' Ft. Mud Weight vis cp Depth Tester Valve 7§59' Ft. TYPE AMOUNT Depth Back Surface 8ubbl e Bottom Cu,hion Diesel Ft. Pres. Valve 7653' Choke hose Choke 3/4" · Recovered Feet of '/ .. · Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Opened t°ol, Cln.~ed_aJ:_surfar. e.for 10 miniJte_~_ flpPnPd at .~u_rfa.¢e ~o_~ minlJte first flow with a light hobble hn_~e blow. Closed tool for fir minnte fir_~t closed in pressure. Reopened tool for 53 minute second flow with a liaht bubble hosBn blow. Closed toolfor 108 minute second closed in pressure. Gauge No. 2859 G~auge No. 2858 GaUge No. TEMPERATURE TIME .Depth: 7664 F.t. Depth: 7690 Ft. Depth: Ft. 72 Hour Clock 72 Hour Clock Hour Clock Tool A.M. m-'1 in Est. °F. Blanked off No Blanked offYes Blanked Off Opened 7' 23 P.M:.. r-- Opened A.M. _Actual 1 ~8°F. Pressures Pressures Pressures Bypass 11 ' 22 P.M. Field Office Field Office Field Office Reported Computed '" , Initial Hydrostatic 3992 3943 3988 3953 Minutes Minutes · -~o Flow Initial 2621 2618 2632 2624 -~ F~no~ 2621 2618 2632 2624 20 21 Oosed i. 311 9 31 02 31 48 31 06 60' 58 -o~ Initial 2621 2618 2632 2629 c o Flow , -- u°':' Final ,,o 2621 2618 2632 2629 42 53 Creased in 2995 3002 3000 301 5 11 7 108 Initial ~3 Flow ~ Final Closed in Final Hydrostatic 3992 3943 3988 3953' FORM Iii-RI--PRINTED IN U,~.A, FORMATION TEST DATA .,-r,-..,. ,.,, ,o. 0/,. Gauche No. First Flow Period Time Deft. .000" PSIG Temp. Corr. 2618 I Depth Time Defl. .000" First Closed In Pressure PSIG Temp. Corr. 2618 7664,' Second Flow Period Time Deft. .000" .000 PSIG Temp. Corr. 2618 Clock No. 10431 Second Closed In Pressure Time Defl. .000" ,o0. PSIG Temp. Corr. 2618 .000 .000 .000 .023 2618 .0044 2723* .059 2618 .0133 2676 .0110 2828 .0267 2741 .0177 2873 .0400 2796 .0243 2925 .0533 2840 · 0309 2970 .0667 2880 · 0375 2998 .0800 2918 .0441 .0508 .0574 3061 3075 .0933 · 1066 · 1200 3090 3102 .0640 2950 2978 3002 ITicket 72 hour No. Third Flow Period Time Defl. .000" PSIG Temp. Corr. 607910 I Third Closed In Pressure Time Deft. Log-~-- .000" PStG Temp. Corr. (;ouge No. 0 -~ ] .023 2 3 4 5 6 7 10 11 13 14 Reading Interval REMARKS: 2858 Depth 7690' Clock No. 10394 2624 .000 2624 .000 2629 .000 2629 hour 72 2624 .0045 2740* · 058 2629 .0136 .0112 2823 .0271 .0179 2875 .0407 2693 2752 2799 .0246 2931 .0542 2845 .0314 2975 .0678 2885 .0381 3010 .0814 2924 .0448 3064 .0949 2956 .0515 · 1085 3081 2990 · 0582 3096 .1220 3015 · 0650 31 O6 Minutes -- *First interval equal to 4 minutes SPECIAL PRESSURE DATA FORM 183-RI~PRINTED IN U,$,A, l', .;ET NO. Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint ................... Pressure Equalizing Crossover ......... Packer Assembly ................... Distributor .......... ~. e r.f.s ........ Packer Assembly ................... Temp. recorder Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... O.D. I.D. 5.75" 2.75" 4½" 3.826" §" .88" 5" 3/4" 5" 3" 5" 1.75' 5" 1" 8.2" 2.44" 2 7/8" 1.49" 3 7/8" 1.99" LENGTH 1 7659' 6.55' 5' 4.05' 5.30' 2.96' 4.64' 8.80' 1.70' 4.54' 3.75' 607910 DEPTH 7653' 7659' 7664' 7677' 7689' 7690' 7699' 3 7/8" PICK UP HEAD 7795'__,RBP TIME ~lorizontal Line Ea~ual t~,'~'lO00 p.s.i. Ticket F L U I D S^ AA P L E D ^ T ^ Dote 7_1 &.?~, NumGer 607911 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOO[~rAT~TJ District ANChOr, GE cc. Oil cc. Water ,,,Tester C. m. BCLA.~ Witness ?AT CT.~NDF. NTN cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY TH · Gravity o APl @ °F. EQU I PAA EN T & HaL E DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested ~ RESISTIVITY CHLORIDE CONTENT Elevation 98 Net Productive Interval Roles 7725' - 7730' Ft. Recovery Water @ °F. ppm Ail Depths Measured From Kelly Bush~ 20' Recovery Mud __ @__ °F. ppm Total Depth.,. 7795i_- Ft. Recovery Mud Filtrate ~ @~OF. ~ppm Main Hole/Casing Size 9 Mud Pit Sample ~ @ °F. p~'n Drill Collar Length I.D. Mud Pit Sample Filtrate @__°F. ppm Drill Pipe Length 7659' I.D. 3.826" Packer Depth(s) .... 7677' Ft, Mud Weight vis / cp Depth Tester Valve 7659~ Ft. TYPE AMOUNT Depth Back Surface Bubble Bottom Cushion NONE Ft. Pres. Valve 7653 Choke Recovered 76 Feetof drillin§ water, Recovered Feet of Recovered Feet of ' Recovered Feet of Recovered Feet of " Remarks Opened tool for 16 minute first flow period. Closed in a .... at surface. Closed tool for 59 m~nute f~rst closed ~n pressure. Reopened tool for 120 m~nute second flow period with a weak blow. UTR - Unable to read. Gauge No. 2858 Gauge No. 2859 Gauge No. TEMPERATURE - Depth: 7664 F,t. Depth: 7690 Ft. Depth: Ft. TIME 72 Hour Clock 72 Hour Clock Hour Clock Tool A.M. __Est. °F. Blanked Off NO Blanked Off ~ Blanked Off Opened P.M. Opened A.M. _Actual 130 *F. Pressures Pressures Pressures Bypass 0915 P.M. -- Field Office Field Office Field Office Reported Computed _ Initial Hydrostatic 3 988 ~T~ 3 992 [J'~ Minutes Minutes . Initial . Flow .... Final 49 52 50 38 16 _ Closed in 197 59 201 68 59 == Initial 49 52 50 40 _ ~.~ Flow. renal 74 54 50 40 120 ~__~ Closed in .~ P/ow Initial ~:~. Final Closed in Final Hydrostatic 3988 4264 3992 4104' ~ , , ,,,, ,i FORM HII-RI--PRINTED IN U.$,A, FORMATION TEST DATA LITTLE'6 96671 1OM 8/74 Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual ClP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint ................ Pressure Equalizing Crossover ......... Packer Assembly ................... Packer Assembly ................... Temperature Recorder ~[~~ ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ m~c~~g.Pick.up..hea~... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total. Depth ....................... 5.75" , 4 1/2" ~'kCK ET NO. LENGTH 607~11 , ,, DEPTH 5II 75" 3.826" 88," .75" 3" 1.75" 2.44" 1.99" 1I 7659' 6,55' m 5' 7653' 7659' 5" 51! 8.2" 3 7/8" 4.05' 5,30' 2.96' 4.64' 8.80' 7664' ......... 7677' 3 _7/8" 3 7/8" 99" ] _- 70f 4,54' ,, 7689' 7690' ...... , 3~75' 7699' 7795' RBP TIME FLUID SAMPLE DATA Date 7-16-75 Number 607912 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Po Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil · cc. Water Tester BOATMAN witness CEENDENIN cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY NM Gravity ° APl ~ °F. EQU I PM EN T & HaL E DATA S --I ., ___m Gas/Oil Ratio cu. ft./bbl. Formation Tested - z RESISTIVITY CHLORIDE Elevation 98 m Ft. CONTENT I Net Productive Interval Holes @ 7725'-7730' Ft. Recovery Water @ °F. ppm All Depths Measured From KellYBushing-20' " Recovery Mud ~ @~ °F. ppm Total Depth,, PPD 8000m, ... .Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/casing Size 9 5/8" - 47# Mud Pit Sample @ °F. ppm Drill Collar Length - I.D. - Mud Pit Sample Filtrate~ @ ~°F. ppm Drill Pipe Length 7666' I.D. 2,44i" Packer Depth(s) 7683 m .Ft. Mud Weight vis .... cp Depth Tester Valve .9? .... Ft. TYPE AMOUNT Depth Back Surface Bottom Cush~on NONE Ft. Pres. Valve 7659' Choke BUBBLE HOSE Choke ,88n ,., Recovered 220' Feet of drilling fluid .~: · Recovered Feet of Recovered Feet of J Recovered Feet of Recovered Feet of Remarks Tool opened with a light bubble hose blow- which continued throughout , , the test. Took a 234 minute closed in pressure. CHARTS INDICATE PARTIAL PLUGGING OF TOOL PIPE PERFORATIONS DURING THE FLOW on PERIOD.. UTR: UNABLE TO READ... ..... ,, Gauge No. 2859 G~uge No. 2858 Gouge'No. T~.ER^TU.E T~ME De~th:, 7665' 7728' Ft. Depth: Ft. Depth: Ft. --I 72 HourCIock 72 Hour Clock HourClock Tool A.M. Est. °F. Blank;d Off ?? ~ 81anked Off '.,' ,YE.,S Blanked Off' Ope. ned 9' 43 p.M._ Opened A.M. __Actuall 30 °F. Pressures Pressures Pressures Bypass 8: 33 P.M. , ,, Field Office Field Office Field Office Reporte. d Computed initial HYdrostatic - U]-R 3047 3916 ' ' Minutes Minutes . ..~o Initial ~.: Flow 88 88 49 121 .... ~. . Fina~ 356 351' 382 387 360 416 _ Oosedin ,664 .... 654 695 .... 692 290 , 234 ~ Initial c o Flow .... u°': Final m~' Closed in " I' r- ~ "Initial ........... ClOsed in ' ' ] '" ...... LFir~al. H~;drost:atic - UTR 3025 3916 ....... o 0 o FORM Iel-RI~PRINTE:D IN FORMATION TEST DATA LITTLE'It 90671 IOM EI/74 2859 First First Flow Period Closed In Pressure 7665' S~cond Flow Period Time D~fl. PSIG Time Defl. - t -f- ~ PSIG Temp. Temp. LogT Time Deft. .000" Corr. .000' Corr. .000" .000 PSIG Temp. Corr. Clock No. 10431 Second Closed In Pressure Time Deft. .ooo', PSIG Temp. Corr. Ticket 72 hour No. Third Flow Period 607912 Time Defl. .000" PSIG Temp. Corr. Third Closed In Pressure Time Defl. Log~- .000" Temp. Corr. e No. 2858 Depth 7728' Clock No. 10394 hour 72 288 347 .0462 345 .0637 . 367 .0813 · 365 .0988 670 387 .1164 · 1340 .1516 .1691 677 · 1867 .2043 680 .2394 Intervol 60 REMARKS: * INTERVAL: 56 Minutes PRESSURE DATA I..ITT~£'I~ 96673 ?SC 8/74 Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve .................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... *~rl~*S%tet~%tAN*. CI.RCULATING .VALVE Pres~~.m~,S.A .F E.T.Y... Packer Assembly ................... ~,s~r~u~r TUBING Packer Assembly Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... D~~s .HT.-5.0.0. re. rap, ....... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... O.D. I.D. 5" · 88 ii 5" 3" 5" 1.75" 5 3/4" 3" 5 3/4" 3.12" 8.2" 2.44" 2 7/8" 2.441" 3 7/8" - 3 7/8" - ~,,~,CKET NO. 607912 LENGTH DEPTH 6.60' 7659' 4.05' 7665' 5.10' 3.9' 3.55' 5.95' 7683' 33.04' 4.07' 7728' .83' 7733' 8000' PBD I,U TIME Each Horizontal Line Equal to 1000 p.s.i. Ticket FLUID SAMPLE DATA Dqte 7-17-75 Number 607913 5ompler Pressure .P.S.I.G. at Surf~c,, Kind Holliburton Recovery: Cu, Ft, G3s of Job HOOK WALL District ANCHORAGE cc, Oil CC. Water Tester C.H. BOATMAN Witness MR. CLENDENIN ..... cc, Mud Drilling Tot, Liquid cc. ._ Controctor BRINKERHOFF DRILLING COMPANY SM Gravity ° APl @ °F. EQU I PM EN T & HOLE DATA ..... Gos/Oii Ratio cu. ft /bbl. Formation Tested - . RESISTIVITY CHLORIDE Elevation 98 ' Ft, CONTENT Net Productive Intervol 6095-6100' Holes Ft, Recovery Water ~ @~ °F. ppm All Depths Meosured From 20' Ke'lly bushing ,.. Recovery Mud @ °F. ppm Totol Depth 7650' PBD Ft. Recovery Mud Filtrote ~ @~ °F. r)pm Main Hole/Cosing Size 95/8 ,, 47# Mud Pit Somple @ *F,- ppm Drill Collar Length 186' I,D, 2 7/16" Mud Pit Somple Filtrote~ @ ..... °F. ppm Drill Pipe Length ?? I.D 2.441" ....... Pecker Depth(s) 6059" '" Ft. , Mud Weight vis cp .Depth Tester Valvq, 6041 m , Ft. TYPE A~OUNT Depth Bock Surfoce Bottom C.,hio. Ft. Pres.. Vo~,~ 6037' Choke 1/4" Choke 3/4" .... .,,. Recovered 93 Feet of drilling fluid , Recovered Feet of ...... Recovered Feet of ' ........ Recovered Feet of ..~ Recovered Feet of ......... Re~rks Tool opened closed in at surface. Closed tool for 60 minute first ,,, ...closed in pressure, period. Tool ceopened for 361 minute second fl'ow period .... with a light blow during test, gas to the surface in 105 minutes of second flow. Closed tool for 360 minute second closed in pressure period. FINAL CLOSED IN PRESSURE OUESTIONABLE ' GoJ'geNo, 3637" Gouge'No, 3636 Gouge'N~), ' i TEMPERATURE TIME ,Depth: 6046 Ft. Depth: 6071 Ft. Depth: Ft. 72 HourClock 72 HourCIock HourClock Tool 7-17 x~ Est. CF. Blanked offno Blanke~l....ChCf .yes 'Bl~nkle. d~ff' Opened.,5: 20. P.M. 6076' ........... Opened 7-18 A.M. Actual , 115 'F. Pressures ., Pressures , Pressures . Bypass 6: 26 Field Office Field Office Field Office Reported COmputed ,,, Initial HydrOstatic' 30~4_... 306'2 3~)R.3 3081 Minutes Minutes. Initial " ~: F~ 1.3~; 155 141 168 ~.~. Final 1 ~6 143 .... 141 154 ., 5 Closed in ~.'{~ 332 335 341 60 initial .... ~ 1 ~36 ,. 1,36 ] .~0 147 ,, )~ Flew Final 13.9 137 1Sg 159 361 Oo~ed ~n 646 641. 652 651 360 Initial .., :~~ Final · Closed Jn _Finol Hydr~)static ~062 "3066 3'0R4 '3086 .... , , ' ...... FORMATION TEST DATA Drill Pipe or Tubing ................ Reversing Sub Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint ................... Pressure Equalizing Crossover ......... Packer Assembly ................... Dm~cm~. P. er. fs .................. Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... e~. ~om~-..HT. :.500..Temp ...... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Oo D, Io D, 3 7/8" !~ 75" 7/8" 1/4" 11 2_ 441" 2. 375" · 88" 11 11 11 1.75" 2.44" 2.44" 2 7/8" 3 7/8" 3 7/8" Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Tota~ Depth ....................... EQUIPMENT DATA T~KET NO. 607913 LENGTH DEPTH 79 186' 4.87" 5.03' 6037' 6041' 4, 04,', m 5/04' 1 ..?, 4.65' 8.78' ' ,6046' 6059' 4.07' 1.04' 6071' 6076' 76.60' P-BD ,, TIME Ticket .~' FLUID SAMPLE DATA Date 7-19-75 Number 607914 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE " cc. Oil ........ ~§' cc. Water Tester C.H. BOATMAN Witness P. CLENDENIN cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY SM S Gravity ° APl @ °F. EQU I PM E NT & HOLE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation 98 m Ft. CONTENT ...... Net Productive Interval 5709-5717 m Ft. Recovery Water @ °F. ppm All Depths Measured From Kelly bushing 20' Recovery Mud ~ @~°F. ppm Total Depth 5900' PBD Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size 9 5/8 47# z Mud Pit Sample @ °F. ppm Drill Collar Length 186' I.D. 2 7/16" Mud Pit Sample Filtrate @~°F. ppm Drill Pipe Length 5446' I.D. 2;441" Packer Depth(s) 5 6 6 0 ' Ft. Mud Weight ,..vis cp Depth Tester Valve 5632' , Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve 5628' Choke 1/4" Choke 3/4" = ', Recovered Feet of Reversed out .~~- Recovered Feet of Recovered Feet of ' Recovered Feet of Recovered Feet of Remarks Opened tool c)osed_..a.t.surface' strong blow- 630 PSI surface pressure in 5 minutes. Closed tool for 63 minute first closed in pressure.period. Reopened tool for 62 minute second flow with a weak blow, fluid in annulus on increasing. Closed for 241 minute second closed in pressure per. lad. INITIAL CLOSED IN PRESSURE NON-USABLE. , , ,, , ,, , Gauge No. 3637 GaUge No. 3636 Gauge No. :~: TEMPERATURE TIME D..epth: 5647 ,,F.tt Depth: 5673 Ft. Dep.,t,h: Ft. i--I 72 HourCIock 72 Hour CIock HourCIock Tool 7-18 ~ Est. °F. Blanked Off no Blanked Off ,yes- ..... Blanked Off I . .... Opened 11' 13 P.M. c= 5678' " Opened 7-1 g A.M. _Actual117,,I °F. Pressures Pressures Pressures Bypass 5' 25 P.M. , ,, ,,, Field Office Field Office Field Office Reported Comp'u~ed .......... -initial Hydrostatic" 2864 2841 2877 2R~9 Minutes Minutes ~] Initial 870 UTR 892 1436 .......... _ Flow Final 870, UTR 892 945 c Closed in 2843 2840 2859 2861, 65 ~q ~?o ...... ~ r- Initial 421 41.9 443 451 o~.~ F~owFina~ 426 424 443 438 ~ ~ _ Closed in 2686 2690 2692 2698. ~mn Initial ...... ~ Final ....... ClOsed in ' ' ...... ~Finol .~;drostatic 2836 I ~005" 2863 ..... 3027 .......... U1 R-.Un.ab 1 e t 0 .re.ad IrC)RM 'I~I-R'I~PRI.NT.IrD IN ~J.~.A. FORMATION TEST DATA, LITTLI~'~ g~87l IOM 11/74 First FlowPeriod Time Dell. .000" 3637 Depth First Closed In Pressure PSIG Temp. Corr. Time Defl. .000" L t+e PSIG Temp. Corr. . "" ~,: . 0000 1729 Unab l · 0690 e to 2840 5647' S"co.d Flow Period Time Defl. .000" .... 0000 .0139~ PSlG Temp. Corr. 419 423 Clock No. 10431 Second Closed In Pressure Time Defl. .000" .. 0000. · O185*~ PSIG Temp. Corr. 424 935 1284 .0256 445 .0359 · :0372 435 .0533 1577 10488 .0707 424 1845 rea .0604 423 .0880 2096 .0720 424 .1054 2307 .1228 2467 .1402 2576 .1576 2648 .1750 2683 .1924 2688 .2098 2690 .2272 2690 446 .2620 2690 2690 ITicket 72 hour No6079 4 Third Flow Period Time Defl. .000" PSIG Temp. Corr. Third Closed In Pressure Time Deft. Log-~ .000" PSIG TemD. Corr. Gauge No. o .0000 1~ 0070 '°/ 11 12 1436 945 3636 Depth 5673' Clock No. · 0000 .0700 945 2861 · 0000 45 l .0132: 438 .0241 456 .0351 447 .0461 438 .0570 436 · 0680 438 Reading Interval ,10 REMARKS: *First interval is equal to 12 minutes· · 0000 · O188*: · 0364 · 054l .0717 · 0894 72 hour .1071 .1247 .1424 · 1600 .1777 .1954 .2130 .2307 · 2483 I 1394 438 947 .,, 1291 1585. 1846 2096 2311 2469 2575 2650 2689 2696 2698 2698 2698 2698 16 .2660 ** = 17 minutes. Minutes SPECIAL PRESSURE DATA LITT4..E'$ 96673 75C 8/74 /~-,,.. . ,T'~ K ET NO. 6079 · Drill Pipe or Tubing ................ Reversing Sub Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly l~sTr ,'b%roV .-..P. e .r f.s.. ............... Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T' Running Case ....... Anchor Pipe Safety Joint ............ aa Do 7/8" 2 7/8" 6 1/4" 5" 5" 5" 8.2" 2 7/8" 3 7/8" 3 7/8" Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collors ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total DePth ....................... I. Do 75" 2. 441" 2 7/16" 3" 1.75" 1" 2.44" 2.44" LENGTH 5446' .... 186' ' 4.'89' 8.47' " 7.18' 4.05' 5.06' 3.52' 4.59' 8.8' 4.09' 1.06' DEPTH 5628' 5632' 5647' 5660' 5673' 5678' 5900' PBD FORM ,,?-RI--PR. INTED IN U.S.A. EQUIPMENT DATA ,,TIME- Ticket F L U I D S A M P L E D A T A Dote 7-21-75 Number 60791 6 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester MR. BOATMAN Witness ~. CLENDENIN cc. Mud Drilling Tot. Liquid cc. Contractor BR[NKERHOFF DRILLING COMPANY BC Gravity_ · APl @ °F. E Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation 98 ' Ft. CONTENT Net Productive Interval Holes 570g' - 5717' Ft. Recovery Wate. r @ Recovery Mud ~ @~°F. ppm Total Depth 5900' PBD Ft, Recovery Mud Filtrate ~ @ ~°F. ppm Main Hole/Casing Size 9 5/8" 47# Mud Pit Sample ~ @~°F. ppm Drill Collar Length 186' I.D.2 7/16" Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length5472' I.D. 3.826" Packer Depth(s).56 75' Ft. Mud Weight vis cp Depth Tester Valve ~.~' Ft. TYPE AMOUNT Depth Back Surface Bottom _Cushion Ft. Pres. Valve Choke 1" Choke 7/8" · Recovered Feet of , ,, Recovered Feet of Recovered Feet of ........ Recovered Feet of Recovered Feet of Remarks Tool opened for a 1052 minute flow. Pumped in 55 barrels of diesel and swabbed. Closed tool for 90 minute closed in pressure. Gouge No. 2859 Gauge No. 2858 Gouge No. ' ' TEMPERATURE TIME Depth: 5659' Ft. Depth: 5688' Ft. Depth: Ft. ' 72 HourCIock 72 HourCIock HourCIock T°°l 7-20-75 ~.~.= Est. 130 ?°F. -'Blanked Off No Blanked Off Yes Blanked Off Opened 9: 58 P.M. Opened 7-21 --~.~ _Actual °F. Pressures Pressures Pressures Bypass 5: 00 P.M. , Field Office Field Office Field Office Reported ComPuted Initial Hydrostatic 2945 2985 2985 2980 Minutes Minutes ~ Flow Initial 75 70 97 89, iZ~. Final 75 200 123 214 1052 CIosedin 201 200 246 209 90 " · o~ Initial u~ Fl°w Final Closed in - Initial ._~.9 Flow ~_~ Final Closed in -- , =Final Hydrostatic 29.45 , 2985 2987 2980 £ORMIel-Rt--pRI.NT.E:DINU.$.A. FORMATION TEST DATA Drill Pipe or TUbing ................ Reversing Sub ...................... Water Cushion Valve ................ . Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler ................... Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... ~e=s~:~ C.ir. culati.ng .Valve Pressure Equalizing Crossover ......... Safety Valve Packer Assembly Perforations Distributor ........................ Packer Assembly ................... FlUsh Joint Anchor ................. Pressure Equalizing Tube ............. Blanked-Off B.T.'Running Case ....... HT 500 Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth .... .................... O, O, I, D, 3.826" 2 7/16" 11 5" 5" 5 3/4" 8.2" 2 7/8" 1.75" 3n 3.12" 2.44" 2.44" .3 7/8" 3 7/8" T~""'~ ET NO. , ~ LEN~"H 5472' 186' 6.60' 4.05' 5.10' 3.9' 3.56' 607916 DEPTH 5653' 5659' 5675' 5688' 5693' ~gO0' PBD TIME Horizontal Line Equal to 1000 p.s.i. Ticket .n~ F L U I D S A M P L E D A T A Date 7-?0-75 Number 60791. 5 -~' Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE ~o cc. Oil · cc. Water Tester MR. BOATMAN Witness MR. CLENDENIN cc. Mud Drilling m Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY DR Gravity o APl @ °F. EQU I PM E NT & HO LE DATA ~.. Gas/Oil Ratio cu. ft./bbl. Formation Tested - I RESISTIVITY CHLORIDE Elevation 98 m Ft. CONTENT -- Net Productive Interval 5709-5717' Holes Ft. Recovery Water @ °F. ppm All Depths Measured From Kellv Bushina 20' Recovery Mud ~ @~°F. ppm Total Depth 5900~BP - Ft Recovery Mud Filtrate ~ @ ~°F. ~~ppm Main Hole/Casing Size 9 5/8-47# Mud Pit Sample @ °F. ppm Drill Collar Length 186' I.D. 2 7/16" Mud' Pit Sample Filtrate @~°F. ppm Drill Pipe Length 5436' I.D. 3- Packer Depth(s) 5648 Ft. Mud Weight vis cp Depth Tester Valve 51~?? Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve 5618, Choke Bubble hosJ~h°ke 3/4" Recovered 90 Feetof drilling fluid .~ ~- Recovered Feet of Recovered Feet of < Recovered Feet of Recovered Feet of Remarks Ooened tool for 235 minute flow with a light blow to almost dead during test. Closed tool for 248 minute final closed in oressrue. CHARTS INDI£ATE I_FAKAGE AFTER APPROXIMATELY' TWO HOURS OF CLOSED IN PRESSURE, g Gauge No. 3637 Gauge No. 3636 Gauge No. TEMPERATURE TIME --I Depth: 5637 F,t. Depth: 5660 Ft. Depth: Ft. I, 72 Hour Clock 72 Hour Clock Hour Clock Tool A.M. c::: Est. 1 20 OF. BlankedOff i. NO BlankedOffY~)s BlankedOff Opened 2' 1 7 P.M. Opened A.M. ~Actual °F. Pressures Pressures Pressures BypasslO' 20P.M. Field Office Field Office Field Office Reporte. d Computed 'Initial Hydrostatic 2950 2953 2969 2968 Minutes Minutes. - Initial -~o 74 72 93 93 ~ Flow ~. Final 57 55 82 77 235 _ Closed in 1167 1167 1185 1185 248 ~ Initial ~.~, Flaw Final ~' Closed in ~ Initial ~o Flow, ~.~ Final Closed in ~Final Hydrostatic J 2950 2953 2978 2968 . FORMATION TEST DATA Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint ................. Pressure Equalizing Crossover ......... Packer Assembly ................... Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... ~x~xm[ HT. 5gO .TEMP. ........ Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... O, Do 11 4½" 6 1/4" 5" 5" 5" 5" 5" 5" 8.2" 2 7/8" 3 7/8" 3 7/8" , m T~.~KET NO. 607915 , DEPTH 3.826" 2.375" .88mm .75" .87" 3" 1.75" 1" 2.44" 2.44" 5436' i86' 4.89' 8.47' 7.18' 4.05' 5.06' 3.52' ', 4.59' 8.8' Perfs ~. 4.09' 1.06' 5618' 5622' 5637' 5648' 5660' 5665' 5900' BP 1,1,,I ' TIME FLUID Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio SAMPLE DATA .P.S.I.G. at Surface ° APl @ °F. cu. ft./bbl. Dote 7-22-75 Ticket Number 607917 Kind of Job HOOK WALL Halliburton District Tester MR. BOATMAN Witness MR. MURPHY Drilling Contractor BRINKERHOFF DRILLING COMPANY BC S EQUIPMENT & HOLE DATA Formation Tested Elevation 98 m Net Productive Interval All Depths Measured From 20' Kelly Bushing Total Depth 5900' PBD Main Hole/Casing Size 95/8" 47//' Drill Collar Length 186' I.D. 2 7/] 6" Drill Pipe Length 5387' I.D. 3.826" Packer Depth(s) 5619 ' RESISTIVITY CHLORIDE CONTENT Recovery Water @ °F. ppm Recovery Mud ~ c~ °F. ppm Recovery Mud Filtrate ~ @ ..... °F. ppm Mud Pit Sample @ °F. ppm Mud Pit Sample Filtrate .... @ ~°F." ppm Mud Weight vis cp TYPE AMOUNT Depth Back Cushion Ft. Pres. Valve Depth Tester Valve 559] ' Surface Bottom 5587 ' - ' Choke - Choke 3/4" Ft. Ft. Ft. Recovered Feet of Recovered Feet of Holes (5759'-5766' (5746'-5754') (5677'-5687') ('5714'-5722') Recovered Feet of No recovery reported Recovered Feet of Recovered Feet of Rernorks SEE PRODUCTION TEST DATA SHEET... TEMPERATURE Est. 5636' @ Actual Hydrostatic '-~o Initial ~= Flow ~-~. _ Final Closed in Initial Flow , Final Closed in Gauge No. 753 De th: ' Ft. 72 Hour Clock · Blanked Off NO Field 2951 2432 2364 2364 2014 Pressures office UTR 175 1327 2695 401 1732 CT[ 2014 FORM ttl'Rm--PRINTm'D IN U,$.A. Gauge No. 489 5631' Ftc. 72Hour Clock Blanked Off Yes Gauge No. Field 2944 2441 2379 Pressures Office 2954 180 1333 2701 £T£ £T£ 2379 2026 26)26 CTE CT-~--~~ FORMATIOh Ft_~. Hour Clock Blanked Off Field Pressures TEST DATA Office TIME Tool 7-22-75 ~.~. O en._.~.~~l: 00 P.M. Opened 7=25 ~ Bypass 1 ' 1 5 P.M. Reported Computed Minutes Minutes 2581 1443 311 2584 1440 73-CTE LITTL°'~ 9~871 tOM Casing perfs ........ Bottom choke 3/4" Surf. temp, 'F Ticket No. 607917 Gos gravity ........ Oil gravity .GOR Spec. gravity Chlorides ppm Res. @ °F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ....... Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks p.m. psi MCF BPD , , , ,, , , 0500 ¼" 725 0530 ' ¼"-3/z" 930 Opened choke to 3/4" on WH Manifold ,, 0615 3/4" 152 ...... 0715 " 200 3/4" choke on Heater Treater .... 0900 " 250 ..... 1000 " 283 1600 · 1030 " 282 1600 .............. 12 30 " 282 1720 ,, 1235 ~4" changed choke for different flow rate , , 1245 " 504 13~00 " 775 1390 1345 " 1285 Changed to 9/64" choke at 1345 Hrs. , , 1400 9/64' 1550 By-paSsed. separator to work on Da'nial 1430. ~/64"- t8" 1975 Orifice Meter. switched to 1/8" Positi choke at WH ,, 1500 1/8" 2000 By-passed separator 1700 " 2000 Went through separator ,, 1800 " 2050 ...... Low Flow rate possible due to Freezing 1945 " 2050 290 off in Positive choke at WH 2000 " Opened to 3/4" choke at WH with 1/8" ' ' chuke at Heater Treater 2030 ,, 1810 530 · 2230 " 1815 ~ ...... 2400 " 1825 420 ,, ......... 'e .o..,.,..,_..,,,,,,,,,,.u...,,. PRODUCTION TEST DATA '""'-"'"'"'"'/'-' Casing perfs. Bottom choke , 3/4" S.r~. temp .,, °F Ticket NoL, 60791,,? ,, Gas gravity ,, Oil gravity GOR. ......... Page 2 Spec. gravity Chlorides ppm Res. INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED , Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks , p.m. psi MCF BPD , ,, , ,,, ,, ,,, 0010 11/64 Change to 11/64" choke , , 0030- ,, 1670 ,, 0130 ,, 1575 0230 ,, 1550 ,,, 0345 " 900 1~25 , Q400 Changed to 15/64" choke 0430 15/64' 1400 1300 '.., 0500 " 1300 0800 " 1330 0800 Closed tool for buildup ,,, ,,, ..... ............. i ii ~ i i ,o,.,.,.,,-,,.,,,,,:,,,u...,,. PRODUCTION TEST DATA "'"'"""'"'"'"'/".... Oo I · ' e . e 8. g. 10. 11. 12. 13. 14. 15o 16. 17. CITIES SERVICE 0.._ COMPANY. Lease (~er/~Com~y NMe 607917 Ticket ~er B.T. 753 B.T. 489 B.T. Page 1 Depth 5606' Depth 563l' Depth . INITIAL FLOW .... ~ ......... ,,, Time Defl. Log t ~- I~ PSIG Time Deft. Log t -~- t~ PSIG Time Deft. t -~- ~ P.~IG Temp. Temp. Log Temp. L .000" ~ Corr. , .000" f:) Corr. .000" t'; Corr. · 0000 i 7 5 -"i' 0000 ..... 1'80 ( :0330i ,2, 9~')BSC~' j "( .0330 .... 298)BSC] _ i ..... (.1330i 458.) E. SC...i ( ( .139_0 462)Es¢1 I ( .25QQ! 305)BSC !! (.2540 305)BSC. i i · 2731 505 ' ......... i ·2759 470 ( .34801 681.) ESC Ii ( .3560 678)ESCi ( .5150! 363)BSC_ (.5190 363)BSCi .5461 . 694 F .5518 657 ....... (.5630 757)ESC. (.5710 754)ES 3 ..... .8192 ..39.6 .8278 399 .,, fl .0390, ,.. 341)BSC ].Q480 , 346)BSC, i iii 1.0922~ i . 1.099 ....... 1.1037 . . 109~ (1.1030 .......l157)ES( 1·1170 ll 5(i).E S C ". ..... (l.ll80 369,)C, 1.1310 372)C ., , fl ,2590 484)C 1.2.740 485)C 1.3653 447 1.3796 .447 (1.5770 , 460)C..... 1.5980 i m 462)C ., 1:6380 1,.,2.26 1.6570 1220 SIX I, NT~!RVA'LS @ 245,,,MINL ES EACH ., 1470 TO"AL iMINU.1ES ..... I' ', CHOKE C.}iANGE ..... l. 7249 .2.,239 ',,l. 7448 .,2260 mmm 1.8119 2345 1.8327 2348 1.89.8,8 ..... 2397 1.9205 2399 1.9857 2427 2·'0084 "' 2490 ,, . 2·0730_ . _2439 2.0940 I,i .2441 i , i -- FIVE I~TE'RV. ALS"i)'I78 M. IN TES EAC[ ...... 390 .TOIIAL MINUTES ...... , ,,, , , ,, .......... ~ cHoKE.(iHANGE.i 2. 1622 ,,23~5. 2. 184~ ), ,Z3.68" i · i . 2.25.!,3 2346 2·2742 ................ 2349. 2·3405 ,. 2370 2.3645 2373 ...... 2·4297 2098 2.4544 ... ,20.99 , _ 2.5188 , 2,0.41 2...544.0, , . 2043 2.6070 2022 2.6380 ...... J2025 , , , SIX INI',ERVAL~ @, 80 MINU ES EACHJ ........ 480 TOI~AL MINUT:S ' ~ , __ ,, i mmm im , , , _c )sure ..... . ES£ = End of surface closure .................... .t2 = .Choke change '' SPECIAL PRESSURE DATA 18. 19: 20. 21o O~ 2. 3. 4. 5. 6° 7. 8. 9. lO. 11. 12. 13. 14. 15. O. 1. 2. 3. 4. 5. 6. 7. 8. CITIES SERVICE 0~. COMPANY. Lease Owner/Co~Dany Na~e B.T. 753 B.T. 489 B.T. 607917 Ticke~ 'Num6e~ Page 2 Depth 5606' Depth 5631 ' Depth ' INITIAL FLOW PERIOD CONTINUED ..... ~'S~G i TimeDefl /n tq-0 TimeOefl. Log.t+0 Time Deft, . t -1t- (~ PSIG I_og~ Temp. I ~^~, ' -vg. Temp. Temp, .000" Corr. ~ .uuu' 0 Corr. .000", ~t~ Corr. CHOKE ;HANGE , i2..6749 ". '.i68'1 ...... 2.7067 1667 ..... 2,7430 1522 2.7754 1518 r : 2.8110 ., 1412, 2.8441 1414 2.8800 1327 ii 2.9100 1333 L! FOUR I II']ER~ALS @ 61 MII~itJTE,S , _L EACH. r 244 TO~FAL MI'NU1ES 1 INil:IA. cLOSED I~ PRESS:lIRE · 0000 1327 II .0000 1 ;]33 · 0334 2631 [i .0337 2634 .0669 2659 Ii .0674 .. . 2663 ..... .1003 . ,, 2669 Ii .1011 2672 .1337 ,. _ 2674 I', .1348 . , . 2677 .... · 1672 . . 2677 I .1685 .... 2679 · 200~ i 2680 l! .2022 2683 I .234l 268l I .2360 2684 .2675....... 2683 .., .2697 2685 . 3009 2684 .... . 3034 2687 .3344 2686 .3371 26RR .5RR5 ",. ,, 269]., .5933 2693 .... .8426 2693 ,,, .8494 .... 2694 1 0967 2694 1.1056 2695 . . 1 . 3509 .2695 ] . 3618 2696 .... 1.6050 .... 2695 1.6180 2701 First 10 in.'l~er~als'e~ua,..],' ,. , ' ........ 30 minLites each; last 5 interva s' ....... " equal ~128 mi nut es each. - SECOND i~LOW PE6IOD ........ . ", ...... " , .,0000 . , 401 CHART 'IME EXP RED .... .... 0111 569* .0212. ' ?63 ..... · 0312 961 · 0412 1i27 .0513 .... i'3'{)5 ~ ......... .0613 1448 . . . .0713 '1589 .0820 1732 ' , 9 minutle intervl]ls: ..... . * ~ 10 r, minutes , before chart time ex,ired .... - , - SPECIAL PRESSURE DATA TICKET NO. 60 7917 Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint ..................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly ................... Perforations Distributor ........................ 11 4½" 6~" 11 2.75" 3.826" 2 7/16" .88" · 75" .87" 3" I _ 7~" 2 7/8" 11 2.44" 2.44" Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ HT-500 Temp. Recorder Packer Assembly ................... Distributor ........................ Packer Assembly ' ' Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... 3 7/8" 3 7/8" EQUIPMENT DATA LENGTH 1 5387 ' 1R6' 4.89' 8.47" 7.18" 4.(lB' B_OK' ,. 4.59' 8.8' 4-0g' 1.06' DEPTH 5587' 5591' 5606' 5619' 5636' 5900' FORM te7-RI--PRIN'I:EO IN U,~,.A. LITTLIE'! .. -;.- ..... . -. , . I.U TIME Each Ho~' .iontal Line E~ual to FLU ID S^MPLE DATA Ticket Date 7-26-75 Number 607918 ' Sampler Pressure .P.S.I.G. at Surface Kind :~- Halliburton Recovery: Cu. Ft. Cos of ........ Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester C.H. BOATMAN Witness G. HARMON · cc. Mud Drilling · --I Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY SM S '. Gravity * APl @ °F. E 'Q U I P M E N T & H O L E D A T A -l~ '' Z Cos/Oil Ratio cu. ft./bbl. Formation Tested - .,, RESISTIVITY CHLORIDE Elevation 98 m Ft. m CONTENT Net Productive Interval Holes at 5576-5586' Ft. Recovery Water @ °F. ppm All Depths Measured From 20' Kelly bushing Recovery Mud ~ @__°F. ~~ppm Total Depth 5640' Plug back depth Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size 9 5/8 47# Mud Pit Sample @ °F. ppm Drill Collar Length 186' LD. 2 7/16" Mud Pit Sample Filtrate @ °F. ppm Drill pipe Length 5311' Lb. 3.826" Packer Depth(s) 5526 m .Ft Mud Weight ,., vis cp ,Depth Tester Valve 5498~ ,,, FtL TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve 5494' Choke _ Choke 3/4" .... · · Recovered Feet of NO recovery reported .~ Recovered Feet of ~ Recovered Feet of ~ Recovered Feet of Recovered Feet of Remarks Tool opened for 122 minute first flow period with a light blow. Closed tool for 238 minute first closed in pressure period. Tool reopened for 1185 minute second flow with strong blow. Closed tool for 1435 minute second CIP period. Tool re.oPened for 257 minute third flow and closed for 343 minute third closed in pressure period. SEE PRODUCTION TEST DATA' SHEET..."C'harts indiCate possib'ie" '~ ,. partial pluqqinq durinq early part of second flow.period. , ., Gauge No. 753 Gauge No. 489 Gauge No. TEMPERATURE TIM£ CC _ Depth: 5513 Fi,t. D. epth: 5538 Ft. Depth: Ft. 72 HourClock 72Houraock HourClock Tool 'TZ26LT~^.M. _Est. ;F. Blanked Offno Blanked Off Yes " Blanked O~..f ~ Opel.ned_._~:35 ~,~A. 5543' Opened7- 28- 75A.~k> _Actual100 °F. Pressures Pressures Pressures ..... Bypass 9; 15 P.M. Field Office Field Office Field Office Rep°rt~'d Computed -lr~itia) Hydrostatic 2881 2887 2896 2902 Mi,ut°, Minutes - initial '~ -3 62 63 73 71 o ~ Flow ~ F~na~ 103 105 ., 111 113 ......... 123 '."'122 -r> Closed in 2667 2670 2671 267,,4. 24,0 238 r- ~ Initial 157 ],.,57 159 163 8.c Flow Final ....... ~ o 1642 1648 1653 1654 1184 1185 __ qosed ~n 2660 2674 2677'" 2678 _ 1439 1435 ~ I~low Initial 9~;2 864 922 1159 ,,, ~b Final _ 857 871 885 882 _ 429 Oo~.d i. 2625 2640 . 26_45_~26~ , 165 _3_43 --~_]no! Hydrostatic j .. 2870 '"i' "288Z_ ~2924 2902 '-°"" ..... '-""'""""'"'"'"'"' FORMATION TEST DATA Casing perfs. 5576-5586'Bottom choke 3/4" Surf. temp 'F Ticket No.~ 6079 C~s gravity .......... Oil gravity .... GOR Spec. gravity. .Chloride~ _ . ppm Res, c~ eF INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ........ [~e Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks ..... p.m., ,,. psi MCF BPD SECOND FL(iW PER !OD ........ , ......... 1230 29/6z " 475 2.1 MMCF ........... 1340 " 500 2.29 MMC~ .................. 1440 ,, 515 2.4 MMCF . ............ 1600 " 560 2.51 MMCI ..... 1700 10/64' 1825 641 MCF .............. · ., 1800 " 1880 691 MCF 1900 " 1890 693 MCF , , , 2000 " 1900 694 MCF ...... 2015 14/64 Changed chokes ........ 21 O0 " 1550 1.34 MMCI 2130 " 1500 1.38 MMCI , 2200 1500 1.33 MMCF , ,, 2300 1530 1.3 MMCF .... , , , 2400 1550 1.26 MMCF ...... 0015 17/64' 1550 Changed chokes 0100 " 1250 2.016 MM(F 0200 " 1250 1.95 -MMCF 0300 " 1260 1.92 MMCF 0400 i,, 1300 1.89 MMCF 0415 " 1300 1.93 MMCF ....... 0422 Closed in 7-28-75 0~1 Opened tool closed at surface ,,, ...... ,,--,,,,T-,,,,u...,,.PRODUCTION TEST RATA Casing perfs.. Bottom choke ....... Surf. temp ,, .'F TicketNo. 607918 Gas gravity, . Oil gravity. GOR Page 2 Spec. gravity ..... Chlorides ..... ppm Res. @ °F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ............ Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks ., p.m. psi MCF BPD 0550 Opened surface ,, ........ 0830 Shut in at surface 1130 2225 Closed in wi th Dual CIP , 1415 o Pulled packer loose · ., , , , ..... ,,, ........... ,, ....... ,, ................... P-O 1 2 3 4 6 0 1 2 3 4 5 6 7 8 9 ~1)0 11 12 13 14 15 CITIES SERVICE OIL COMPANY Lease Owner/C6mpany Name 607918 Ticket Nt~e~ B.T. 753 B.T. 489 B.T. Depth 5513' Depth 5538' Depth . 72 Hour clock 72 Hour clock Time Deft. Lo_t + 0 feSm~ Time Deft. . t + 0 PS'G g-- P. Temp. Temp. LOgTI Time Dell. Log t a-, 0 .000" 0 Corr. .000" Corr. .000" l) Corr. FIRST,.,FL, OW-P-/iII,OD .... ~ _'?!RST ~FLOg:P~RI-Ob_: ]g2 m~nute's t°tal .0000 63 .0000 71 .0245~ ...... 64' '. ,0~".. ~ _:76 '. .... .'0468~ ....... 71 ..... .0479 80 .069] ..... ~7 ~ .0707 : ., 87 .0914 83 .0934 90 .......... .]137 88 .1162 . 96_ ., ,1360 10~ .1390 .... 113 ... 20 m~ !Ute ~ntervals 20 minute intervals .. *F~rs~ interval is *F~r~t interv~]""~- equal to 22 m~ nates, equal tO ~-m~,~utes."~ FIRST CIP PER ;OD F!.RSJ CIP PERIOD ::238 m~nutes iota..] . .. . oooo,, ] os ....,. o90,0. , ] ] 3 .0156'~* 1369 ~0157'* 1279,~ , ...... , ,,, , .0334 218] ~0335 ... 2138 .05]2 2494 .0514 _2485.]. . , .069i "' 2598 ........ ,0693 259.8 ........ , 0869 2635 .0872 , _ :2637 .'1047 , ~ . 265~ ~ ~"10~,1 .... 2655__ .122~' ,., 2658 ! ~.j22~ 2~62 .... .1403 2663 [ .1408 2~7 .]582 2665 _ .1587 , ,2,670: .. .1760 2666 .1766 2671 ., J ,,. ,, ~ · . . . 1938 2667 . ]945 2672 ' .2116 2669_, .21~3 :: 267~ ...... ~ ....... .2294 2669 .2302 2674 .2473 '" 2~70' 2481 .... 267~'' 2650 ' 2670 ".2~'~0 ......... 2674 '-' :, ~: ~ ..... 16 ~ ~ute ~nt~,rVals,. ".~] ,]~ m~njte eqUal to 14 minutes. ] equ~].~O 14 m~butest . . SECONI FLog PE:RiOD '"s~CON~':F[O~-p~'OD '1~85 F~rst'~O Bin[tes seg~ :Fir~('50 miou~:es ~'mSeg: ] ~ :] ~. ] : - ~en~-iff-5' ~0 ] meqted in 5- ~)0 minut~ interva~iS minute intervals ,0000 ]5~ .0000: :~ -~G3 ..... . ] 004 ....... ~ 30'9 ] ~6" ' ~i 300 '" . 2008 826 · 2032 828 .......... - 3012 : : ~797 .3048 -804 .4016 834 - :~4064-:~ ...... ~ '839 ,5020 :: ~_ 8.67 ..... .5080 ........ 87~ - --,, ~hang~ ................. ~ ......... ,d chokes ~ Chang?t.chokes[ .................... _ _ : _ ~: ~ : ~ ...... : : SPECIAL PRESSUR]! DATA CITIES SERVICE OIL COMPANY Lease O~mer??jomPan7 Name B.T. 753 B.T. 489 607918 (Page 2) TiCket Number B.T. Depth 5513' Depth 5538' Depth . P-6 7 8 9 lO 11 12 13 14 15 16 17 18 19 20 21 0 1 2 3 4 5 6 7 8 9 lO ll 12 13 72 Hour clock 72 Hour clock Time Deft. Log t -Jr- 0 PSIG Time DefL i. t ~r- (~ PSIG t PFIG ! Temp. .000" .,~, Corr. Corr. r') Corr. - / .o00" Log Temp. _ SECOND :FLOW P.[_RIOD ...... SECOND FLOW PI~RIOD '[~ON¥~-.) .... "' _._ 253. re. ir ute choke chang~ ~-f ~'n-6-~' ~hS~tke c'hail'~ie' .. _ .5611, .... 2205_ ._5677i~. _ .]:_ ~: ~2~.3.......... .... 61..69 ..... 2319 .6240 2324 . = .67.27 2331 .6804i ..... 233G: .~ . . , 7285 .... 23...35 · 7367, f§39 _ . 7840 , 23.3~ , .793.0, .. .... 2)41 __50 mintte ifitervals 50 miuute inte_rvals ·.*First interyaJ is~ .. *FirS)~'intervhl is ........ equal 1.o..53 minutes ...... equal, t'9 ...53 m'[nUteS.il .... ' ' " 242 mir ute'_.chO'ke ~ch'an..qe '2~2"m' nute choke Chali~[e -. 8398*~ . ! 9..34 .... · 8492,~*. 1936 ..... .8933 1888 .9032 1891 .9469 1898 ~ '"' 9'571 1'90'2' .... 1. 0004 1916 .... l'.O111 1921 . ,, 1.0.540 ..... .19.44. 1.0650 1947 · _48 minu.le intervals 4~ mi)~ute int(!rvj'l's- ...... ~'WF.i.r.s.t interval is **F~'r]t i'nte~;,a'l' i's eaual tc 50 mjn~t6s.' ' ' ~equailto '50-'ni. nu'te~, " ]240 mi.nt.te choke Change 240 m~nute ch6k% Cha~6 .... _L_0~86 1619 =: i .-i-0-97 ........ 1 ~5 ~ -. ,.. "', .... l. 1433 1592 l. 1543 1598 _l. 1879 1'~08 ' "l. 199'b 16'l'l" _1.2325 162] .... 1 2437' - ' 1~627 I _l ,2772 ' 163'8' 1,'2-f84 ........ 1643 ..... l. 3220 ........ 1648:1 ~ 3~jO- ......... r-T~4 - -~0 minute intervals 40 mintite int~-~val's ........... SECOND- ('IP PERI~)') ........ -S'~D-,~~rOD-=~35-minut~iS t6t'al "' =. ooOo ' j' ..... T-TeST ...... : , 101:5*~ ~ ..... -~6i 0 ...... .-1ULF6'*-'!* .... "[~3- ~ .... · 2085 :2627 ~--~ - '~-2~FO ::' ........... _~.3156 2637 ;-T319]-:[]: ~ ~63r9 .... _. ,4-226 2643 "': 4~74 ~ -2648 . -_~. 5296_ ..... - , 26-4T--i! .-'7[F3~6 2[5-5"'-/[-- =.6367 2654 J ' .~l'--' '~ 8508 2661 .9578 2665 ~ ~68 1,06~4.8.. : _ 26_67 ~12-07-69 r - 267]--.., : 1. 1719 2669 -]l.-'[l)Sl--[ 26T--- - 'l'.2'789 .... 2671 TT. Eg~T- ~77F-~I~i ]'-]~- i' ,.1~...3.,8.~._ ..,_,.., 26¢2_=_1t1'-_401_ff-~ _ __---'2-676. · ***First (nterval is equal to 91 minutes. .. SPECIAL PRESSURE DATA F ~ . _CITIES: SE~JLlJ3[ O!L_~J~J~N]~~ Lease Ovner/Comptmy N~mte ' _ _ 607918. (Paoe 3) Yicket Nm~e~ - B.T. : ....753 B.T. __480 B.T. Depth 5513' _ Depth _5538' Depth . P-14 15 0 1 2 3 4 5 6 7 8 9 lO ll 12 13 14 15 72 Hour clock Time Deft. IG .ooo,, '-°"-'7-- I .ooo,, l-oo--r- [: .0% - l..4030 2672 1. 5099 2677 ] ~.~nnn m I 26.74, 'i 1,.61.80 .... --~6_78 ........ _ 96 minu:~e inter~als 96 mincte inte~:vals THIRD F' (~w PFRIi)D THIR 0 : ~' OD-' 25;rm~-~in~tes t°.tal - 0000 864 .0000 ], :'l i 59 I: 0040'B'.S 860) .~:~.S.' :, :: 9~__.) ..... ' .... .0469' .... 25~3' 1:04_77' | .... 2577 "' 0949 '2847 ,09~6__ ! J' 2i5~0 i .... [:097'021~S . 2~47) (':'~8_0~..S: ':~ --, 2650)" ... '"'. ..... · 1430 ....... 951 .14..5.4 ........ 962 ..... ... · 1910 : 9.00'- I · 1943 911 .2390 .... 880 .2432 891 .... _ · 2870 . . . 871 .2920 882 43 .mi,nJte jnte-vals 43 minute inte~,vals · Fir. stinterVa is *Firstlinterval is e~ual tO 4,2. mi ~u.te~: i equal ~o 42 miridi~es~:" .. ..:. ,i i ! THIRD liP PERIOD" THI'RD CIP PERiCiD - 34: minu'%es itotal ' 'bOO0 .... , -- tm mm, 87.1 --' ::~ : ~0 ...... 7 882 ..... . ,.. .02.3...4*1~' 2188 ] :0236-';v''* 2~01 · 0490 ~ ' 2507 '. 0494 "~ 2~) 2 ...... .0746 ' . 2570 .075~ .... ~. 2574 · · 1003 ' 259_ "~ lO1-----0 . 2~95 ...... .12~9 " .~.- 2604 t 1269 .': 2607 ...... .1515 2612 15~-7 26--'13 .~ ' _ .)771 .... 26)7 1785 -- · 26-i8 .... _ __ · 2027 ..... 26-~1 :"~ 2043 2~'2'4' .2284 ' 26-~6- -~301 "- 2628 ..... 2540 26~- .2560 : : ~ 2628- 7 ......... - .2796 2630 i 2'gTg'-'" ' j-2-'6'32 ~"i' ' ' .3052 26~2 I 30-¢"6"- f-2~6-~4 ; ....... · 3308 2635 '~ 3334 ~638 ..... :'.,, ' ..... ..... 3565 . , , 2637_. -! 3592 · _. -2639 ..... .3820 2640 ,l :3850 .... 2'641 .... .. 23 minute intel~vals [ **~_interva~]' i's ......... · *Firs b interg-~l is '~-~3 minu~te interlvals equa.1 ~o 2]'m~fiU't~. i~21' mil~u,,t.e.'s ! '.'. ' _ ' ,1 i ;] r :, 1 :I ,..'r-q, a.,~.~,-/';;':,i ' . ~'~,, ~ i '- ; - - - r. ..",, _ _ ~ ..... ' ~'1~'~ _ __ ~ - 't"' : ..,"'_ _ _ · : beginning of su.face osure ce dlOsUr~ SPECIAL PRESSURE DATA' Drill Pipe or Tubing ................ Reversing Sub . ' .................... Weter Cushion Valve ................ Drill Pipe ........................ Drill Callers ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Duel CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint - AP Running Case .................. Hydraulic Jar .................... VR Safety Joint ................. Pressure Equalizing Crossover ......... Packer Assembly ................... ~st~o~t~-. P. erfs .................. Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... HT - 500 Temp recorder Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint .... ......... Side Wall Anchor ...... : ........... Drill Collars ...................... 11 ,, 4½!.' .. 6 1/4" 5U 5" 5" 5" 5" 5" 8.2" 2 7/8" 3 7/8". 3 7/8" ._ I, Do _ 2_ 75" 3,826" 2 7/16" .... ,88" .75" · .87" 3" 1.75" 2.44" 2.44" r ~KET NO. LENGTH 1 5311' 186' 4.89' 8.47' 7.18' 4.05' 5.06' 3.52' 4.59' 8.8' 4.09' 1.06' 607918 DEPTH 5494' 5498' 5513' 5526' 5538' 5543' Flush Joint Anchor ......... ......... 81anked~Off B.T. Running Case ........ Totol Depth " ~__ ,. u..... EQUIPMENT DATA 5640' LITTLE'~ 96676 75C 0/74~...~ TIME · Ticket F L U I D S A M P L E D A T A Date 7-30-75 Number 607920 -Sampler Pressure .P.S:I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil ..... cc. Water Tester BOATMAN Witness HARMON , , cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY NM Gravity ° APl @ 'F. EQU I PMENT & H aLE DATA , Gas/Oil Ratio cu. ft./bbl. Formation Tested ' RESISTIVITY CHLORIDE Elevation 98 ' Ft. CONTENT Net Productive IntervaHOLES@ 43'64"4369' 5535"5545' - Ft. Recovery Water '@ OF. . ppm All Depths Measured From KellY Bushing - 20, Recovery Mud ~ ~~ °F. ppm Total Depth 5560' - PPD Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size 9 5/8" - 47~ Mud Pit Sample ~ @ ~ OF. ppm Drill Collar Length 186' I.D.~ ,, Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length 4094'1 I.D.3,826" Packer Depth(s) 4307 ' Ft. ......... Mud Weight 1 O vis cp Depth Tester Valve 4282' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion NONE Ft. Pres. Valve NONE Choke NONE Choke 3/4" · Rec0,vered Feet of Recovered Feet of Recovered Feet of i~ Recovered Fee~of ~' Recovered Feet of ,, Remarks NOTE' FIRST AND SECOND CLOSED IN PRESSURES WERE MISSED. ....... SEE PRODUCTION TEST DATA SHEET... SEE SPECIAL READING SHEET AND DATA SHEET # 2 FOR THE FOURTH FLOW AND FOURTH CLOSED IN PRESSURE. ...... ............. Gouge No. '753 Gauge No. 489 Ga"ge 'N6. ' ....... TEMPERATURE TIME , ,Depth:, 4294' Ft. Depth: , 43! 9,'Ft. Depth:, . Ft. '72 HourCIock 72' Ho,rOock HourOo~k'T;o~-'30-?5 .... ^.M. _Est. .°F:, BlonkedlOff N0 elqnked ~ff'l YES BlapkLd ~ff ....... Opened,, 1' 55 P.~4. 4324' @ Opened7- 31 - 7 5A.M. _Actual ] ~) °F. Pressures Pressures Pressures Bypass 1600 P.M. Field Office Field Office Field Office Report~;~l ' Computed Initial Hydrostc~'tic 2238 2243 2257 2259 ~i.~t,, ..~o 'Initial'"181 211 182 " '232 ~.: Flow ,- , ~-~. Final 153 162 155 160 IZO _ C)o~ed ~n 2234 21 O0 2248 21,08 225 2'23 -~ Initial 210 213 222 225 §.9 Flow ........ ~,~ r~na~ 245 249 249 252 192 204 ~, Closed in 2238 2121 2244 2113 .... 253 g~ F,ow Initial '342 332 345 .. 340 ~ Final 511 354" 516 36i .... /65 //5 Oos.d in 2146 '2153 "' 2159 .... 21571 m m 425 -Final HYar0~iotic ) 2246 '"2257 2276 2267 -' FORMATION TEST DATA · L. ITTL. er'e geel71 lam e/74 Ticket F L U I D S A M P L E D A m A Date 7-30-75 Number 607920 ,- Sampler Pressure .P.S.I.G. at Surface Kind Halliburton .= o Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil · cc. Water Tester BOATMAN Witness HARMON cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY NM S Gravity °,APl @ °F. EQU I PM ENT & HOLE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested ,., RESISTIVITY CHLORIDE Elevation Ft. --I CONTENT ,. Net Productive Interval Ft. 4=, Recovery Water @ °F. ppm All Depths Measured From Recovery Mud @ °F. ppm Total Depth Ft. Recovery Mud Filtrate .__ @__°F. ppm Main Hole/Casing Size :;o Mud Pit Sample @ °F. ppm Drill Collar Length I.D, Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length I.D. Packer Depth(s) .Ft, Mud Weight vis c,p Depth Te~.ter Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke .., Recovered Feet of "' / Recovered Feet of , Recovered Feet of , Recovered Feet of Recovered Feet of .,, Remarks FOURTH FLOW REEADINGS AND TIHES Gauge No. 753 GaUge. No. 489 Gauge No. TEMPERATURE TIME --I I ,, Depth:,, ZJL~9~I-' F,t. Depth:, 4319' Ft. Depth: , Ft. ]L~,Jr Clock 72 Hour Clock Hour Clock Tool A.M. cz ,,Est. , °F. 'elank,e~l Off NO Blanked Off YES Blanked Off " Opened , P.M. Opened A.M. _Actual 'F. Pressures Pressures Pressures Bypass P.M. , Field Office Field Office Field Office Reported C~nputed - , Initial Hydrostatic Mlnufes MinuTes · .~ Fio~.0J~l~t~ 413 4Z2 ~-Z FOL~iT~H 956 962 315 324 Closed in 2124 21Z4 90 ' ~ Initial c o Flow . r'- u°~ Final _ Closed in ,~ Initial _~_o IZIow ,. ~.~ Final . CloSed in ..... Final HYdrostatic ' . -- _ _ fORM tgi-RI--PRINTED IN FORMATION TEST DATA ~i~ ~rf$ ..... I~tl~m choke ~urf, letup ,,, 'F Tt~ket No .... ~07~0 Gas gravity Oil gravity ...... GOR Spec. gravity .... Chloride~ .... .npm Res. @ °F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Date 01 5 5 Choke Surface Gas Liquid Time a.m. Pressure Rate Rate Remarks 7-30-~..q. Size mi MCF BPD 0155 3/4" ,I ' Opened tool with a medium to a strong blow.. 0210 " 15 0220 " 19 0225 " 20 Gas to the surface - turned to trap 0355. . " 0 , 1st closed in pressure period. 0740 " Opened tester with surface closed in. , , , lO00 " .Opened at the surface, ii02 " 2nd closed in pressure. 1315 . Opened tester. 7-31-75 ,, 0200 3rd closed in pressure. 09-15 'Opened tester and 200 PSI immediately surfaced. 1430 Closed tool bled gas and reversed out. 1600 ...... Pulled packer loose and dropped down.. below the lower perforations and rever., OUt.. 2400 Out of the hole with the tools... .., , , , ed ,o..,,,.,,-,,,,,,,.,,,,u...,,. PRODUCTION TEST DATA ,.,.r,..,.. ,,,,. ,, ,/,:,..- Gouge ~o. , ........ 75,3 First Flow Period Time D~fl. .000" .000 PSIG Temp. Corr. 211 201' 184 167 163 161 161 157 162 i Depth 4294' First Closed In Pressure Time Deft. .000" .000 .249 L t~-8 PSIG Temp. Corr. 162 21'00' Second Flow Period Time Deft, .000" .000 · .160 .228 .... PSIG Temp. Corr. 213 576ASC 249 i ,i, Clock No. ii 10431 Second Closed In Pressure Time Defl. .000" PSIG Temp. Corr. Ticket 1,72 hour iNo. Third Flow Period Time Defl. .000" · 000 249 000 · 148 2121 .0604 (. 0660 . 1070 1070 · 1922 .3239 .4557 .4730 .5730 .5875 PSIG Temp. Corr, 332 704** 716ASC 348BB) 468AB ) 461 483 732 767ASC 739ASC 387 607920 .... I Third Closed In Pressure Time Deft. .000" · 000 .0304 .0620" .0935 · 1250I · 1566 · 1881 .2197 .2512 .2828 .31'43 PSIG Temp. Corr. 2096'*' 2123 2131 2136 2140 2143 2144'1 2147 2148 2149 2150 2152 2152 2153 2153 (.6710 .7193 (.7590 (.8470 .8510 738ASC .3458 534 '.3774 '743ASC : .4089 517ASC .4405 354" .4720 Gauge N°. .0180 .0348 3 .0517 '°I 11 12 13 489 Depth 232 .000 160I'' 201' .252 2108 187 165 4319' · 000 "225 " . 158 5'76ASC' .226 252 Clock No. 10394 hour · 000 .149 '252 '11 .ooo 2113 II .0620 lj(.0670 11(.' o9o 11(.' 2oo !t .1973 H .3327 Il .4680 72 340 683** '719ASC 355BB) 477AB) 463 490 7'19 .ooo ;0305 .062] .0937 ·]253 .]569 .1885 .2201 · 0686 163 .0854 .1023~ .1191 163 160 156 .1360 160 ** IN' ERVAL 1155 MINU ES. BB = BEFORE BYPASSING. AB = AFTER BYPASSING] Reading Interval 1 5 RE~RKS: * INTERVAL = 16 MINUTES. CLOSURE. (.4890 767'ASC .2517 (.5910 7'4'0ASC ·2834 .6033 400 .3]50 (.6880 738ASC .3466 .. .7386 539 .3782 .7770 J 743ASC~ .4098 J 1.8670 J 517ASC~' ".4414 I ii1 i '-28" *** INTERVAL "'~7 .... IINUTES. ASc': APP~RkNI 5U~FAU~ ALL READINGS ON THE THIRD FLOW ON B.T. # 753 ARE 361 2100'* 2125 2135 2141 2145 2147 2148 2151 2152 2154 2156 2156 2157 2157 2157 , Minute~, QUESTIONABLE DUE TO CLOCK MALFUNCTION. ,o,, ,,,.,,-,,,,,,o ,, u.,.,. SPECIAL PRESSURE DATA L. IT?L.I"$ 94J75 75C 8/74 CITIES SERVICE OIL ~'"gANY Lease (]X~ner/Company Name 607920 icket Numb'er. B.T. 753 B.T. B.T. 489 Depth 4294' Depth Depth . 4319' P-O P-1 P-O P-1 P-2 P-3 P-4 P-O P-I ,P-2 P'3 P-4 P-5 P-O P-1 P-2 P-3 P.4 P-5 P-6 P-7 P-8 P-9 P-10 72 Hour Clock 72 Hour Clock .~ Time Oefl, t + {~ PSIG Time Defl. Log_t -~- 8 P.~IG Time Deft, Log Temp. Log Temp. Temo. .000" Corr. .000" ~ Corr. .000" f~ Corr. _ FOURT~ FLOW PERIOD- ~ L. FOURTH'FLOW PERIOD' - _, 324 MINUI~ES'TO',AL ..... 324 MINLTES TOTIL , FIRST lOG MINUTES (A. FTI R CHOKE CHANGE) '' FIRST lC6 MINUTES(AFTER _ SE'~ME~TED INTO i'READI .~ OF ' SEGMENTED INTO 1 READIN 26" MI N LITES ' AND 5 READi" SS"OF" ' 26 MINUIES AND .~ READIN - 20 M'INUTES EACi~',. ,. , . "" 2'0 MINU1ES EACH .'.' -- 24 MIN3TES REO)RDED BE~ ..... 24 MINUIES'RECOFDED BE- i,,, FORE fIRST CHO',E CHA,,N~i. , ', , ' FORE ¢IF ST CHOKE'C~IA,.NGE .000 413 .000 422 .0263 256 " .0270 ' 268 -_ 106 Mi~OTE CHOICE CHANG . ' ...... 106 MINUTE CHO~E CHANG .0555 248 ' " ~0564-.. 261 , , · 0779 41~ .0791 421 I · 1004 41~1 . 1017 422 ,,, , _ .1228 4ZZ .1244 425 .. _ .1450 4z~ ~ ' .1470 " 425 _ 20, M,INJTE INT~I~VALS. , .... , 20 MINLTE INTERVALS. FIRST ~EADIN~ N 106 FIRST FEADING IN 106 _ MINUTE CHOKE CI~ANGE : " MINUTE CHOKE CC AN~E : 26 MINJTES". ....... 26 MINLTES. ' _ _ , ,,, ,1 , _ ] 94 MIN 3IE CHOKI' CHANGE ]94 MI~ UIE CHO~ E CHANG · ]926 ~ 891 .]96] ' 896 ' __ · 225l ~z8 ........ .2'298 934" .2576 ' ~43 .... .2635 949 -- .2900" 95i..... .2972 950 .3225 9b~ .3309 · 3550 ~b~ ' .3650 ~ou _ 30 MIN JTE INTEI~VALS. " 30 MINETE INTEFVALS. FIRST ~EADING iN 194 ...... FIRST ~EADING IN 194' MINUTE CHOKE' CilANGE : ' MINUTE CHOKE CF ANGE": _ 44 MIN JTES. 44 MINUTES. FOURTH ;LOSED IT FOURTH CLOSE~" IN PRESSUR' - 87'R]'.NUTES'. ' " PRESSU6E- 81 MINUi~5'. · 000 956 .000 962 -- · 0067 1942**~ ~W. ........ .0068 "' 1910'* .0167 .... 2046 " ' .0169 2048 _ · 0268 2079 ...... ,, ' . 0270 .... .207,7 _ · 0368 2091 .0372 2094 · 0468 21'03 ' ,, · 0'473 ' , 2l 03 ' .0569 "' 2108 ' '.0574 ~' '211'0 , , ,,, , , ,, ..... .0669 2114 .0676 2115 -0769 2118 ' ' ' .0777 2119 .0870 ' ',' '~120 ' ........ .087'9 2123 '~.~'-~'~J7n' ?'! ?zl.-' .0980 9"MINUTE INTERVALS. 9 MiNUi~. IN~.~VALS." ****** INTERVAL : 6 MINUS'ES. - · . . .. .. sPECIAL PRESSURE DATA CHOKE CHANGEi OF OF ww**w*"INIERVAL = 6 HimUTES. · ' OUl~U · Drill Pipe or Tubing Reversing Sub ...................... 11 I II.,IkF. I I.D. LENGTH DEPTH Water Cushion Valve ................ Drill Pipe ........................ 4~'' Drill Collars ' 6~" Handling Sub & Choke Assembly ...... Dual CIP Valve ................... 5" Dual CIP Sampler .................. Hydro-Spring Tester ................ 5" o Multiple CIP Sampler ............... 2 7/16" Extension Joint .................... 5" AP Running Case .................. 5" Hydraulic Jar .................... 5 i, VR Safety Joint ................. Pressure Equalizing Crossover ......... 11 Packer Assembly ................... 8,2" Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... l~~& . H.T.-.500..REC.O. RDER . . Anchor Pipe Safety Joint ............ 3 7/8" 3 7/8" Packer Assembly ................... Distributor ........................ Packer Assembly .................... Anchor Pipe Safety Joint ............ Side Wall Anchor ...... · ............ Drill Coilars FlUsh Joint Anchor .................. Blanked-Off B.T. Running Case Total Depth " ~'ORM IBT-RI~PRINTEO IN U,I.A, EQu I'PMENT DATA 1 4094: , 186' .88" 4.89' 4275' .75" 8.47' ~Z82~ .87" 7.18' 3" 4.05' 4294' 1.75" 5.06' l" 3.52' 2.44" 4.59' 4307' 2.44" 8.8' - 4.09' 4319' - 1.06' 4324' 5560' PBD LITTL,'S 0eeT~ 78C TIME Ticket FLUID SAMPLE DATA Date 7-29-75 Number 607919 .',~ ~ , Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil . cc. Water Tester BOATMAN Witness HARMON cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPAN;{ NM S Gravity ° APl @ °F. EQ U I PM E N Z & H 0 L E DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested - --I RESISTIVITY CHLORIDEcoNTENT Elevation 98 ' Ft_=. Net Productive Interval Holes (553'5'-5545') Ft. z Recovery Water @ °F. ppm All Depths Measured From Kelly Bushing - 20, , ....... Recovery Mud .... @ °F. __ppm Total Depth PPD - 5560' Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size 95/8" - 47// Mud Pit Sample @ °F. ppm Drill Collar Length 186' I.D. 2 7/16" Mud Pit Sample Filtrate~@ °F. ppm Drill Dipe Length 5280' kD. 3.826" Packer Depth(s), 5495 ' ,,Ft. Mud Weight ., vis cp Depth Tester Valve 5467' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion NONE Ft. Pres. Valve 5463' Chok~BUBBLE HOSE Choke 3/4" · · / Recovered 93' Feet of drilling fluid Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Tool opened with a weak blow- 1# on the bubble hose. Closed t°ol for a 122 minute first closed in pressure. Tool reopened for a 73 minute second flow with a weak blow. Closed tool for a 352 minute second closed in pressure. Tool reopened with a weak blow for a 116 minute third flow. Took a 91 minute third closed in pressure. Tool reopened for a 13 minute fourth flow. No fourth closed in pressure was taken.. NOTE- THE FIRST C.LOS,ED IN P.,RESSURE APPEiRS TEMPERATURE Gauge No. 753 Gauge No. 489 Gauge No.T0 BE A SURI'ACE CL0r~RE.. __ Depth: 5482' Ft. Depth: 5507' Ft. Depth: Ft. 72 HourCiock 72 HourCIock HourClock m(~oI 7-29-75 A.M. ---I I Est. *F. Blanked Off NO Blanked Off YES Blanked Off Openea3' 35 =P~./gt'T cn 551 ~ '@ Opened =~./~.= _Actual 1 O0 °F. Pressures Pressures Pressures Bypass 6' 32 P.M. ,, , , , , Field Office Field Office Field Office Reported Computed '-initial Hydrostatic 2~ 5(::i ~b{3 2880 2876 Minutes Minutes ~-~ot~.r. Flow Initial 49 55 62 60 ~-~,., F~na~ 47, 45 62 , 59 ,.. 120 129 aosed in 424 425 429 432 125 1 22 _ ~-o J'~itial 43 50 59 59 ' c o Flow .... 3=' ~o.~ n~o~44 44 59 58 80 73 r- C~osed ~n' 152'i 1 525 1 540 1 5'42 352 352 ~ Flow Initial47 56 62 ._ 67 ~... Final 47 49 I62 64' " 1 0' 116 Clos.d in' 828 .... 834 .... 848 849 ....... '" 88 91 Final Hydrostatic J' 2856. "' 2845 " 2880 28'70 ' rtl z FORMATION TEST DATA LITTLF.'$ 96671 1oM 8/74 Ticket FLUID SAMPLE DATA Date 7-29-75 Number 607919 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE O cc. Oil cc. Water Tester BOATMAN witness HARNON cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRTLLING COMPAN~ NM S Gravity ° APl @ °F. EQ U I PM E N T & H O LE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested --4 RESISTIVITY CHLORIDE Elevation Ft. '"' CONTENT -I~ Net Productive Interval Ft. Recovery Water @ °F. ppm All Depths Measured From I Recovery Mud ~ @~ °F. ppm Total Depth _Ft. Recovery Mud Filtrate ~ @ ~°F. ppm Main Hole/Casing Size Mud Pit Sample @ °F. ppm Drill. Collar Length I.D. Mud Pit Sample Filtrate @ °F. ppm Drill I~ipe Length I.D. Packer Depth(s) .Ft, Mud Weight vis .. cp Depth Tester Valve . Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke · Recovered Feet of :.~ Recovered Feet of Recovered Feet of ~ r'- Recovered Feet of Recovered Feet of Remarks .. ,,, FOURTH FLOW "'Gauge No. 753 Gauge No. 489 Gauge No.' ' ' ' TEMPERATURE TIME ---I Depth: 54821 Ft. Depth:, 55071 Ft. ...,Depth: Ft. I 72 Hour Clock 72 Hour Clock Hour Clock Tool A.M. c: Est. °F. ""Blanked Off NO Blanked Off ., YES l Bla~ked Off , ..Opened , P.M. / Opened A.M. _4,ctual °F. Pressures Pressures Pressures Bypass P.M. ,, ,,, , ,,, , , , Field Office Field Office Field Office Reported ComPbted ,, ,, Initial Hydrostatic Minutes Minutes -- .~o FbwFOLt~ 51 60 ~ Z F-O-I~N~PH 49 .... 64 12 13 Closed in -o.o 'Initial ~ c o Flow I'- u°'r- Final ClOsed in , Initial ~o Flow : ~ Final , Closed in ..................... Final Hydrostatic ............. ,,.,,,:,,,u.,.,,. FORMATION TEST DATA Gauge No. 753 ,. Depth .5482' Clock No. 10431 72 hour No. ,,,, F i rst F i rst Seco n d Seco nd Th i rd Th i rd Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure PSIG Time Deft. PSIG Time Defl. t -{- ~ PSIG Time Deft. PSIG Time Defl. t-I-~ PS IG Time Defl. i PSIG Time Deft. I Log t -t- 8 Log Temp. Temp. Temp. Temp. Log Temp. Temp. .000" Corr. .000" i Corr. .000" Corr. .000' ~ Corr. .000" Corr. .000"i Corr. o .0'00 55 .000 45 .000 50 .000 44 .000 56 .000 49 1 .138 45 . O158 81' .082 44 .0179 154** .131 49 .0112 175*** 2 .0294 147 .0447 303 .0213 271 3 I .0430 183 .0715 441 .0314 358 ~ 4 .056b 233 .0983 567 .0415 442 s .070t 267 .1250 ...... 684 .0516 521 ... 6 .083/ 297 .1518 791 .0616 589 . 7 .0973 330 .1786 893 .0717 653 8 .1 108 364 .2054 994 .0818 718 9 .1244 398 .2322 .... 1082 .0919 774 l0 .1380 425 .2590 1160 .1020 "' 834 11 .2858 124-2 .... 12 .3126 1318 13 ,3394 1 389 ......... i'4 .3662 ,, 1458 .... ~5 .3930 1525 Gouge bio. 489 Depth 5507' Clock No. 10394 hour 72 o .000 60 .UUU' 59 .000 59 .000 .............. 58 .... .UOU .... 67 ........ 000 I " 64 1 .146 59 .0158 92* .083 58 .0181 165'* .131 64 .0113 185'** 2 ' .0294 158 .0452 314 .0215 278 3 ' .0430 192 ...... .0724 453 ...... .0317 357 ,,, 4 .0566 240 .0995 582 .0419 449 .. s .0701 264 .1266 696 .0521 525 .......... a .0837 299 .1 538 804 .0623 597 ... 7 ' .0973 333, .18091 907 .0724 672 8 .1108 371 2080 1004 .0826 735 9 .1244 404' " .2352 109'5 .... .0928 .... 788 ~o ...... .1380 432 "'. 2623 11,78 .1"030 849' !!1 .2895 1260 12 I 3166 .- 1336 "' ~3 .34'37 1407 ...... 14 .3709 1476 1~, i .,, I .3980 , 1542 ........... Reoding in't'erva' I4 12Mi 24 9 Minutes REMARKS: " * I~ TERVAL '= 1 NUi~_5. ** INTERVAL : 16 MINUTES. ~** INlERVAL : IU RINUi~_5. ' ...... ..... ........ ,,,, , , , ,, ,,, ,, , ,,,,, ,,, SPECIAL PRESSURE DATA C~,u,,cjeNo., ..... 753 ,. DePth 5482' Clock No. 10431 72 hour No. ~i~t. FOURTI First j Second Second Third Third Flow Period Closed In Pressure1 Flow Period Closed In Pressure Flow Period Closed In Pressure ,, , PS'IG Time Deft. PSIG Time Defl. Time Dell. Temp.PSIG Time Dell. Log t Jr- ~ Temp.PSIG Time Deft. Temp.PSIG Time Deft. Log Temp. Temp. Log t -I- ~ Temp. .000" Corr. .000" i~ Corr. .000" Corr. .000" Corr. .000" Corr. .000" ~ Corr. 0 . uu0 b i 1 .Dis 49 2 3 4 5 6 7 8 9 10 11 ,. 12 13 14 15 Gguge No. 489 Depth 5507' Clock No. 10394 hour 72 o' .000 60 .... I ~ .015 64 2 3 4 5 6 7 8 9 ,, 10 11 15 R;odi'nc~ Intervc~l j ' , ..... " " , , M i'n'utes REMARKS: FORI~ ~83-RI~pRINTED IN U.S.A. SPECIAL PRESSURE DATA LITTLE'S 96673 75C 8/74 ~ ' ' 'r XET NO. 607919 Drill Pipe or Tubing Reversing Sub . .- .................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple ClP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint ................ Pressure Equalizing Crossover ......... Packer Assembly ................... Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... ,l:;r~,qe;~HT.-. 500..TEMP ........... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor Blanked-Off B.T. Running Case . Total Depth ........... ". ........... O.D. I.D. LENGTH 2'75"'1 4½" 3.~Zb" 6¼" 2 7/16" 5" .88" 5" .75" 5" .87" 5" 3" 5" 1.75" 5" 1" 8.2" 2.44" 2 7/8" 2.44" 3 7/8" - 3 7/8" - I, 5280' 186' 4.89' 8.47' 7.18' 4.05' 5.06' 3.52' ', / 4.59' 8.8' 4.09' 1.06' DEPTH 5463' 5467' 5482' 5495' 5507' 5512' 5560' PPD · ' _- · . : ...::_:...::. . - . . s · . FLUi D SAMPLE DATA Ticket Date 8-3-75 Number 493654 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. on ' MR. GENTRY ......... cc. Water Tester MR. PURITT Witnes.s G. HARMON cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY SM S Gravity ° APl @ °F. EQU I PM EN T & H O L E DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDE Elevation 98 m Ft. CONTENT Net Productive Interval 4096-4116 ' Ft. Recovery Water ~ @ __ °F. ppm All Depths Measured From 20' Kel. ly. b..us hi ng Recovery Mud @ °F. ppm Total Depth 5560' PBD ..... Ft. R~overy Mud Filtrate ~ @ ~°F. ppm Main Hole/Casing Size 9 5/8 "47// Mud Pit Sample @ °F. ppm Drill Collar Length 186' LD 2 7/16" Mud Pit Sample Filtrate~ @~°F. ppm Drill ,Pipe Length 3811' I.D. 3. 826" Packer Depth(s) 402'4' Ft. Mud Weight vis.. cp .Depth Tester Valve 3999' ,, I,, Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke 1/4 - 3/4''choke .75" Recovered Feet of No recovery reported · Recovered Feet of Recovered Feet of ~ Recovered Feet of .RecoVered Feet of Remarks Opened toot at 0610 8-1-75 With a strong blow with gas to the surface at .... 0648. Closed tool for 134 minute first closed in pressure period. Tool reopened for 1204 minute second flow period. CloSed tool for 1446 minute second closed in g pressure period. Tool reopened for 125 minute third flow period and closed for 49 minute third closed in pressure period. Reversed out of holes Out of hole at GaugeNo. 753 Gauge No. 489 GaugeNo. 1300, TEMPERATURE TIME .... Depth:4011 F:. Depth: ,4036Ft. ,Depth: Ft. " 72 Hour Clock 72 Hour Clock Hour Clock Tool 8- 1- 7J~.M. Est. m°F' 'B'lanked Off no ' ,, Blanked Off Yes 'Blanked Off" .. Opened,.061,0 - 4040' " ~ m m Opened 8-3-7~M'." __X,c,tua~90 °F. Pressures Pressures Pressures Bypass 0,9,] 0 P.M. Field Office Field Office Field Office RePorted Computed ........... -J'hil:ial.. ~ Hydn3statiClnitial 1212 001 1208905 21 12 051 21 11807 Minutes Minutes ~.= Flow ............. ,:~ Final 9! 96 97 .... 103 I 60 -57 Closed in 2027 2013 2018 2017 132 134 ~= Initial 96 108 104 115 ........ ~.~ FI°w- F~no~ 1183 1179 1186 1185 ..-]225 1204 Closed in , 2_0_22 ..... 2015 , 2018 20] 6 1458 19~o flow -In~itial 650. 665 642 670 ....... ~ ~l': Final 620 671 684 685 - 125_ .... J~"~'~ CIosedin :~1c]07 1902 '1901 r-- i902 - . ....... 49_.. Fino, Hydrostot!_c- = 21__]1_3 _2__08_9 2_097 :. 210__7 --- . i i i , i i.i iJ , ......... ,i im L .... __ I .ozj FORMATION TEST DATA P-O 1 2 '3 4 5 6 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 CITIES SERVICE OIL ~OMPANY Lease (X~ner/Company Name 493654 Ticket' Number B.T. 753 B.T· , , 480 , B.T. Depth 4011' Depth 4036' Depth 72 Hour clock 72 Hour cl t q- (} 'PSIG ' "' ' | . ',--n '"J- PSI;' - -: Time Deft Time Deft. !. r -1- ~t i ~ , ' ' Temp. Time Deft. Log--~-- Temp. .000" J ~og---~--- j ICeomrrP.. i .000" Log ~ Corr. .000" Corr. .J, .... ! _ .. .-~ · , _ FIRST FLOW PER'.OD FIRST ~[-~,OD- 5, minutes . .o, ooo .....~-o5 ...... . oooo .... 118........ · 0079* 114 [i .0080* 118 : .... , . , , , _ ·0191 1!6 .... ,0194 .... .122~ .. · 0303 105 ~ · 0308 112 · 0416 ,.I 88 ..... i~ . o,.422 1'02 , I_]. 0528 94 :: . 0536 i00 · 0640 ~ 96 " ,0650 103 ..... -- _ . ,, ..,10 minute. . . inte'va!.s 10. minl!te intmvals ..... ~i *First: interva is ',.*First interval is .... equal to 7' n~l n'~ tes. equal.. ~o .7.... mi nt tes. ......... FIRST-'SIP PERIiJD FIRST CIP PEri,OD - 1:4 minutes ' " .... , · 0000 96 .0000 103 .009~*~ 392 .0091*~ ' 4~'3 .., , [ , , , · 0190 . 768 .... ·0!94 7.7..3 ...... .0291 il 14 .0297 1 ] 22 .0~92 ..... 1403' .040~).. 1399 ' · 0492 ~ - lg-38'" ·0503 " 1630 ' ' · 05~g ' '' 1822 ...... .0605 1823 · 0694 1939 -] 07.0..8 ........ .. 1938 .......... · 0795 1988 .0811 1990 , · 0895 2004 · 0914 2007 , ,,,, ,, · 0996 2008 · 1017 2012 · 1097 ' 2012 .1119 ' 2016 .... .... ;11'97'2012 .1222 " ' 2016 ' ' · 1298 ' 20i3 · 1325 .... 2017 ~ .... - __ · 1399 201-3 .142--8- ~ ' 2017 .1500 .......... 2013' .1530 ......... 20-17 9 minu ;e inter~'als -- 9 min~'t9 interv,als .. '.." " . ' · *Firs~ intervitl i~ **Fi rs t "{ n[ervaj] is. - eqaal''' ;o 8''~mi niites2 ~eq'ual "-i~o 8/hinu[t~s. i" ' . .... ' ....... I SECONDI FLOW pEF,,IOD~ SECOND ~.I. OD: '1~C4 mi/i~t~es tbtal .. First [98 minul:es j,FirSt 4)~e-§ ........... S'"~gmen~ed in 6-83 ]!se m~t_~..d in 6 8) -- minut~ interVais, -~- minut~-Tntbrvais' ' ] .0000 108 .0000 " , 115 '-- · 0938 '314 0'9-4-9 .... 31 ~--- ~ .1877 .... 3~0. ~1897 379 ..... ; 281'~ 396 ~ 2'84~ 406 . · 3754 507' !,.37§4-] ' ' 5i"B ...... .4692 511 i .4743 g~i-' t ....... · - ".'$630 525 5690 537 (cont ..on p.ag.(2) ---,'~go.nt_z' .... >n:::page_ ~i_'i'iii_i SPECIAL PRE. SSURE, DATA P-7 8 CITIES SERVICE 01- COMPANY Lease O~er/Comp~n¥ Nme 493654 (Page 2) Ticket Numb'er ~ B.T. ... ?53 B.T. 489 B.T. Depth _ 4011 ' Depth 4036' Depth . 9 10 11 72 Hour clock 72 Hour clock 12 13 14 15 16 17 18 19 20 21 22 0 l 2 3 4 5 6 7 8 9 l0 ll 12 Time Dell, Log_t. iF- ~ PSIG i ' Time Dell. t_L~_~ ~_.- PSIG Time Deft. I Jr' (~ PClG l Temp. ] .000" Log Temp. Log Temp. .000" t') Corr. Corr. .000" "--~---- Corr. _ sECON[)"FLOW PERIOD SECOND, FLOW PEI~IOD (C~T~). 2315 mirl,ute cho[e 'chJng6 ~-~ ~-~-~ c~](e Chanh,~ ..... _ .61~4, 1614 .,6227 .... i' .,i]1,61.1 ,, , , , , · 66,98 ,. , 16.99 · 6764 I 1702 -- L_. 7232 1731 .,73..02. i 1733 · 7766 1749 ~ .7839_,, ]J7~3 ...... ' ..... _ .8300 1762 ! ·8380 , ? . 1765 _L 47 mint te intervals 47 min~Jte in'te.vals ..... ,, ,,, , _ 235 mil ute chQke 'change , 2'35 milute cho~e' ch'an~l: ' , _ . 8832 15,29 .8.917 1535 ~ . 9364 . 1508 .9454 151'"3 ...- ' , .989§ 1492 ..9992 , . 1498, 1.0428 1471 1.052,9i 1477 1.0960 1455 1. 1070 1461 _ 47 mimlte intervals 4.7,,.m.inu':e .inter /als , ,, , _ 30 minL'te ch.ok~ chanae 30 n~U':e .choke~ Ch. anqe ~ " _ l. 1310 1297 1. 1410 1,,3,03 "' ..,, _ 206 mirute..C, hok..~ chanae 206 m, in_~l~te chok,~, chanq.~ _ l. 1779~ ] 195- i 1;]_890' .... 12QO ., _L 1. 2237 118.9 , .,1. 235~__ 1196 1.2§95, 1183 1.2827I 1188 _ 1. 3152, , 1186 1. 3296 ' '119'4 " ' _ 1.3610 .... 1179 1. 3760' 1185 ..... _ 41 mim te intervals ,, ~1 minu_i:e inter,~als · First int. e,.nval is )*First in'terval"is ,, __equal ,~o. 422,minutes..., ~,equal' t( 42 mi"nt tes.' ...... ._SECOND CiP F~'ERi )D ' '~-ECOND'"'(',IP PERIOD__~l~46im. inutes .0000 ll7~ ". 0'000 1185 ...... · 1151 ** ' ].9.24.... .'1165'** -'i 927 ' ~ .2234 1955 . 2'26~' , 1.958 ,, ,, _ .3316 1975 i~.3359 1978 4399 ' i985 ~, 4456 "i-,989 , __.5482 ,, 1994 !.5553 .... 1996 ' ' __.6565 ., 1998 .664'9' ~ '"2'001 .... _ .7648 ..... _2_002 ,'-7746 2005 " ' _ . 8731 2005 · 8843 21007 ...... _ . 9.,8,1.4 2066 · 9940 " ~20'0'9' 1. 0897 2 QO.8.. il. 1037 -- 2011 .... 1. 1980 .... - .... 2010 ]~-2i 33 2012 ........ , , , 1.3063 2011 1.3230 2013 - ** : 1"02 minute; . ~ **"'-:-l'O;minutes Sp£0IAL PRESS[~! DATA. P-13 14 15 0 1 2 3 4 5 6 7 8 9 10 CITIES SERVICE OIL COMPANY Lease (Xmer/C6mpaa~y Nmne 493654 (Page 3) Ticket NmOoer B.T. 753 B.T. 489 B.T. Depth 40l l' Depth 4036' Depth . 72 Hour clock 72 Hour clock SECOND :IP ~i6 .... ~~D CIP PERI~~ - _~ ~.6~0 20~ ~.652c 20~ .... _96 minute !,~ter~,a]s ~. ~~e in~yals ........ ' ~~p F_oW'PERI~D T~iR~~ ~E~IOD , :1~25 minute tota~ _.~000 65~' ~ :0~00 ~~- ' ....... .02so* 63~ ~ ;0~6. ' [.,,64i-~ ' ..... _ . 0504 706 0515 7 ] 8 _ . 0728' ~ ~97 . 0744 710 ' _ 0952 69] . 09~2TM 705 · ]]76 677 .]20] 69l · ]400 67] , ]4~0- ..... 685' ~20'minut:e intern,als ' ' ' 20 minute intar~a~i ~ ?~F~rst ~nterva~ is "~Fi~s~i]nterva~l is equal t).25 m~n~tes. ~ JTHIRD ~[P PERiO[~. THIRD' S'IP PERIOD ~49 ~inute total ' -' 0000 67] .0000 ~~ .... ' ..... _ . 0047** i ~3~ .0~ ~ ,, ./ 1699 ....... _.0~05 .. ~780 ~ ~0103 .... 1%f6 .... .0'163 i ~4 .0~ --T~ 0 ..... - ~-i '1~0- - . 02'17- 1~] ..... . ......... ~ 05'12 ........ ~i~~8~ '~3 ' ~8~6 ..... -~0570 " ' 19~~]-~0' ' 1502" 5 minU':6 inter~als~~~~~~~-~-- · *Fi rs: ~r~ ~ s ~~~f~~ .......... _]_ ~qua 1~. ~~~es. equa ~o '~ ~'--'~ m~ nu~es. --~- ' ..... ~:. ., ~ ~ ..... . , ~., , ~ - .~ _ .... , ,,. . .. , ,, , , ,, i ,, , , ,, ,, , L . , ,, . . . - ., ...... , , ......... ., =.-- ,, , ~ ..... ~ - _ ............... . : ,~ . .] " ,.= _ .... ~'~'' . ~=~ . . , , ., , SPECIAL PPJiSSUI~ DATA ~. · 7~KET NO. Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly ................... O. Do 11 4~" 6 1/4" 5I, 5" 5" 11 5n 5n 8.2" 2 7/8" -e~o.~,-..Per.f.s ................ Packer Assembly ................... Flush Joint Anchor .............. . . . Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... eellars. HT..-.. 500. Temp ..... Anchor Pipe Safety Joint ........ re. corder Packer Assembly ................... 3 7/8" 3 7/8" Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... I:lu~h Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... Jo Do 2.75" 3.826" 2 7/16" .88" .75" · 87" 3" 1.75" 2.44" 2.44" LENGTH 1 3811' 186' 4.89' 8.47' 7.18' 4.05' 5.06' 3.52' '. 4.59' 8.8' 4.09' 1.06' 493654 DEPTH 3999' 4011' 4024' 4036' TIME ,, FLU ID S^MPLE DATA Ticket Date 8-4-75 Number 493655 Sampler Pressure .P,S,I,G, at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL., District ANCHORAGE cc. on MR. GENTRY cc. Water Tester MR. PRUITT Witness MR. HARMON cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY DR Gravity ° APl @ °F. E , Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDE Elevation 98" Ft. CONTENT Net Productive Interval 3719-3727' Ft. Recovery Water ~ @~ °F. ppm Ail Depths Measured From Kelly Bushing 20' Recovery Mud @ °F. ppm Total Depth PBD-4075' Ft. Recovery Mud Filtrate ~ @ ~°F. ppm Main Hole/Casing Size 9 5/8-47#, Mud Pit Sample ~ @ °F. ppm Drill Collar Length 188~ I.D.2 7/16" Mud Pit Sample Filtrate @ °F. ppm Drill [mipe Length 3468' I.D. 3.826" Packer Depth(s) 3686 ~ Ft. MUd Weight !.0 , vis cp Depth Te~, ter Valve 3473' ., ,, ., ..,.. Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke 1/4-1 / 2" Chol~j/4" · · Recover, ed Feet of .... · Recovered Feet of '' Recovered Feet of Recovered Feet of Recovered Feet of Rerna;ks Opened tool for 62 minute first flnw with a _~trnng blow and gas at surface. Closed tool for 128 minute first closed in pressure. Reopened tool for 32 minute second flow. Unseat packer at 21.27, reset packer at 21-30. Reopened tool for 41 minute third flow. Closed tool for 45 minute third_: closed, in pressure .... CLOSED IN PRE.SSURES NON-USABLE DUE TO POSSIBLE LEA~(AGE. Gauge No. 753 Gauge No' 489 Gauge No. TEMPERATURE TIME __ , ..... Depth: 36,7.3, Ft. Depth!, 3698, Ft. Depth: Ft. ,, .. 72 Hour Clock 72 Hour Clock Hour Clock Tool A,M, Est. °F. Blanked (>Cf ,No" Blanke~ offYes Blank'ed Off ,.Opened. 1 7; 45 P.M. 3,~99' @ ' ' Opened A.M. _Actual 80 CF. ,,Pressures Pressures Pressures Bypass 2~'/~0 P.M. Field Office Field Office Field Office RePorted Compuf~d Initial Hydrostatic 1 gl 1 1 905 1906 1901 Minutes Minutes .,.~o Initial 227 181 151 I~-: Flow 1 Bg ......... N:~ Final 181 261 171 235 -_ aosedi, 964 [EA~AGE 951 ' lEAKAGE .128 Initial 210 200 ' Il 96 ........ ::c o Flow 21 R. , 8-~ F~nal 222 '256 ~206. ~. 270 32 Closedin .387 BYPASS'ED '3-7'2 BYPASSED ' ' _ ........ !~ r,o~ Initial 272 ~g ,~. ~Final 275 ....... 0 41 Clos~-d in M f s Sad .... Mi s s ed ' ._~5 Final-~-~dr°Stati(~ j ' 1921 1923 19_19]'..19'16 ... - m FORMATION TEST DATA Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... 11 aa Do 4½" ~ I/4" 11 5" 5" AP Running Case .................. 5n t. D, Hydraulic Jar .................... VR Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly ................... 2.75" 3. 826" 2 7/16" ,75' 5" 11 8.20,, ,87" 3.00" 1,75' 1.00" 2.44" Distributor ........................ 2 7/8" 2.44" Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... Drill Collars ...HT.-5.00. Temp.. Rec. Anchor Pipe Safety Joint ............ 3 7/8" 3 7/8" Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... , ,, FORM 187-R$--PRINTED t~O[JI PMF~NT ,, DATA ~,~CKET NO. LENGTH 493655 DEPTH I 3468' 188' 4.89' 8.47' 3473' 7.18' . 4,05' 5.06' 3,52' 4,5~)' 8.80' Perfs. 3673' 3686' 4.09' 1.06' 3698' 3699' U.I TIME FLUID SAMPLE DATA Ticket Date 8-7-75 Number 60782,9, Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job H00]( J6[ALL .... District ANCHORAG'-~ cc. Oil .. cc. Water Tester GENTRY & PRUITT Witness G, HARMON ,, cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANy TH Gravity ° APl @ 'F. EQU I PM E N T & HO LE D Gas/Oil Ratio cu. ft./bbl. Formation Tested ,. RESISTIVITY CHLORIDE Elevation 98 t Ft, CONTENT - Net Productive Interval 3084" - 3094t Ft. Recovery Water __ @__ °F. ppm All Depths Measured From Kelly BushfLnp; 20" Recovery Mud (~ °F. ppm Total Depth 3735' Ft. Recovery Mud Filtrate __ @ __°F. ppm Main Hole/Casing Size 9 5/8" 47~ Mud Pit Sample ~ @__%c. ppm Drill COllar Length 188t I.D. 2 7/16'' Mud Pit Sample Fiitrate~ @~°F. ppm Drill Pipe Length 2810' I.D. 3.826'" Packer Depth(s) 3028 ! .Ft, Mud ,Weight 10 vis cp Depth Tester Valve ~O] 5',,.. Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke 1/4" 3/4*' Choke .5/8'" · · Recovered Feetof No recovery reported · Recovered Feet of Recovered Feet of,,. Recovered Feet of Recovered Feet of ~ , Remarks Opened tool for 60 minute first flow period with a medium blow to strong blow. Gas to surface. Closed tool for 121 minute first closed in pressure. Reopened toOl for 67 minute second flow period° ~ Pulled packer loose & started out of hole with dry pipe. Charts indicate partial pluqqinq of ancJlor DerfnrationR durino initial flnw n~rind .... Gauge No. 489 Ga~uge No. 753 ' Gauge No. TEMPERATURE TIME Depth: ~0~ Ft. Depth: ~0~2 Ft. Depth: Ft. 72 Hour Clock 72 Hour Clock Hour Clock Tool A.M. Est. °F. Blanked Off NO BlqnkeclOff VI~,~ Blanked Off Opened 1 ] '~7 P.M. 3046 Opened A.M. ~ Actual 74 °F. Pressures Pressures Pressures Bypass RAc~ P.M. Field Office Field Office Field Office Reported COmputed .., Initial Hydrostatic 1692 1570 1708 15~l Minutes Minutes '*-3 Flow Initial 461 335 270 363 I~-c ' ~Z~ Final 461 337 516 390 60 Closed in 517 669 561 678 ]21 ~ Flow Initial 337 390 Final Closed in _ Initial ~3 Flow ~.~. Final Closed in ......... _Final Hydrostatic 1690 1565 1700 15,79 ,, ,o..,o,..,_,..,.,-,,o,.u...,,. FORMATION TEST DATA ,.,..,.,,,.,,,,,,o.,/,, Drill Pipe or Tubing ................ Reversing Sub ...................... S'! Water Cushion Valve ................ Drill Pipe ........................ 4, S0tt Drill Collars ...................... 6,25~ Handling Sub & Choke Assembly ...... Dual CIP Valve .... ' ............... 5tt Dual CIP Sampler ........... . ....... Hydro-Spring Tester ................ 5tt Multiple CIP Sampler ............... Extension Joint .................... 5~ AP Running Case .................. ~ Hydraulic Jar ..................... 5'~ VR Safety Joint .................. 5t~ Pressure Equalizing Crossover ......... Packer Assembly ................... 8.20't ~. Per. rs ................. 2 7/8" Io Do TICKET NO. 607829 LENGTH 2.75" 2,826" 2 7/16" ,88" 1.00' 2810' 188' 4.89' 8,47' 3,00" 1.75" 1.00" 2.44" 2.44" 7,18' 4,05' 5.06' 3.52' .. 4.59' 8.80f DEPTH 3016 ' 3028' Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... 3 7/R" x:R~Mt~x:HT~S0O..Temp.Re, .... 3 7/8" Anchor Pipe Safety Joint ............ -; Pocket Assembly ................... Distributor ........................ Packer Assembly ................... 4.09' 1,06' 3042 ' 3046' Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... Z735' , FLU ID SAMPLE DA m A Ticket Date 8-4-75 Number 493656 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Ges of Job HOOK WALL District ANCHORAGE cc. on MR. PRUITT cc. Water Tester MRo GENTRY Witness G. HARMON cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY SM S Gravity ° APl @ °F, EQ U I PM E N T & H O L E DA TA Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDE Elevation 98 m Ft, CONTENT Net Productive Interval 3647-3651 ' Ft, Recovery Water " @ °F. ppm All Depths Measured From Kelly bushing 20' Recovery Mud @~ °F. ppm Total Depth 3609 m Ft. Recovery Mud Filtrate ~ @ ~°F. ppm Main Hole/Casing Size 9 5/8" 47# Mud Pit Sample ~ @ ~ °F. ppm Drill Collar Length 188' I.D. 2 7/16'" Mud Pit Sample Filtrate~ @ °F. ppm Drill Pipe Length 3374' I.D. 3. 826" Packer Depth(s) 3592 ' Ft, Mud Weight ]0 vis cp Depth Tester Valve 3379' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres, Valve Choke Choke 3/4n Recovered Feet of NO recovery reported · Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of · . Remarks Opened tool at 0450 8-4-75 with gas to the surface at 0506, had 20 PSI. F.lowec thru i/2" needle valve...opened to sump...bied well down to 1-1~ FSI. Closed tool for 125 minute first CIP period. Tool reopened for 58 minute second flow period, --with immediate blow with 4# FSI. Closed [oo~ tar z48 minute second UIF period with 3½ PSI surface pressure. Tool reopened for 256 minute third flow with 40 PSI immediately. Closed for ii9 minute third CiP period. Tool reopened for 136 minute ~4th flow with fluid to the surface in 3 minutes. Closed tool for 180 minute 4th CIP period. Reopened tool for ii8 minute 5th flow and closed for 250 minute 5th closed in pressure period. Reopened for 53 minute 6th flow and closed for 60 minute 6th CIP Gauge No. 753 Gauge No. 489 Gauge No. period. TEMPERATURE TIME _ Depth: ~.i~J F.t. Depth: ,~ Ft. Depth: Ft. 72 HourClock 72 HourClock HourClock Tool 8-4-7~,.M. _Est. °F. BlankedOff ,p~ BlankedO~f ypc; BlankedOff Opened 0450 ~P/J~. 3609' Ope.ed 8-5-7D.M. _Actual ~ °F. Pressures Pressures Pressures Byposs 0834 P.M. Field Office Field Office Field Office Reported Computed _..-initial Hydrostatic 1860 1852 1868 1 895 Minutes Minutes .~ Initial 173 162 165 171 ~.c Flow bl~. Final 275 271 276 275 61 Oosed in 1715 1701 '1716 1727 125 ~ Initial 269 260 264 266 c o Flow ou'c Final ~. 277 271 273 278 58 _ O°sed in 1701 1700 1714 1727 248 ~) Flow Initiam 284 284 286 289 ~.~ ~mol 381 359 357 388 256 Oosed in 1671 1659 1670 1687 119 _ _Final HYdrostatic 1858 1823 1834 1862 -- ,.. .... i ~ORM 185-RI~PRINTE~D IN U.S.A. LI?TLE'$ ",, FORMATION TEST DATA '""'o-'/" '\ / Ticket F L U I D S A M P L E D A T A Date 8-4-75 Number 493656 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK tUALL District ANCHORAGE ,= cc. Oil Mi{. FI{Utll ~. cc. Water Tester MR. GENTRY Witness G. HARMON cc. Mud Drilling Tot. Liquid cc. Contractor BRi[NKEEHOFF DRZLLING COMPANY SM S Gravity ° APl @ °F. EQU I PM E N T & HOLE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation ' Ft. CONTENT Net Productive Interval Ft. Recovery Water @ °F. ppm All Depths Measured From Recovery Mud @ °F. ppm Total Depth Ft. Recovery Mud Filtrate ~ @~ °F. ppm Main Hole/Casing Size Mud Pit Sample c~ °F. ppm Drill Collar Length I.D. Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length I.D. Packer Depth(s) Ft. Mud Weight vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of · Remarks Fnllt~t-.h_ f{Fth_ and ~yfh F]nw and r']nc~rl ~n n~-~cc~ ~,nnd~nn¢ ....... ~ ...... ;~ .............. ~ ............. i- , Gauge No. 753 Gauge No. 489 Gauge No. c::: TEMPERATURE TIME Depth: 3580 Ft. Depth: 360~ Ft. Depth: Ft. 72 H°UrCIock 72HourClock HourCIock Tool A.M. .,,Est. °F. Blanked Off Fie Blanked Off vas Blanked Off Opened P.M. - Opened A,M. _Actual °F. Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office RepOrted Computed -Initial Hydrostatic _ Minutes Minutes - o~o~low Initial 365 366 ~ Final 200 ~08 13~ ~- Closed ~. 1618 1 652 1 ~o~low Initiol 288 345 ~.Lm~ Final 381 415 118 _., Closed in 1623 1656 250 ~_c:~lowInitial 298 353 >~ ~-~ Final r-' ,~,,, 275 300 53 Closed in 1 567 1 593 60 -' Final Hydrostatic - - -- FORMATION TEST DATA FORM lei-RI--PRINTED IN U.S.A. LITTLE'$ gO~7! $OM 8/74 Gauge No. First Flow Period 753 I Depth 3580' First Second Closed In Pressure Flow Period Time Deft. PSIG Time Defl. t-~-~ PSIG Time Deft. PSIG Temp. Log Temp. Temp. .000" Corr. .000' i Corr. .000" Corr. .0000 162 .0000 271 2O2 .01 977 .0124' ,0000 · 0090*: 260 248 Clock No. 10431 jTicket 72 hour No. 493656 Second Third Third Closed In Pressure Flow Period Closed In Pressure ~ PSIG TimeOefl. I PSIG Time Defl. .~ PSIG Time Deft. Log Temp. Temp. Log Temp. .000" Corr. .000" Corr. .000" Corr. · 0000 271 , 0000 284 · 0315**~* · 0238 200 .0280 1374 .0202 239 .0540 · 0392 .0504 .0616 .0728 · 0840 · 0952 · 1064 1604 ..0351 1669 1684 1691 1694 1695 1698 (.0290-] 311 277 .0314 .0426 .0538 · 0650 241) 252 273 265 268 271 .0765 271 · 04 64 · O990 .1215 · 1440 · 1665 · 1890 .2115 · 1176 1699 .2340 · 1288 1700 . 2565 · 1400 1701 .2790 11617 1676 1683 1688 1691 1693 1695 1697 1698 1698 1699 1700 ·0577 .0630'~*~ 422 · 0990-~gC 422) ,1080 483 ,1530 '. 1650-E ,1980 · 1990-B ,2430 .2660-E ,2880 603 623) 391 392) 575 601) 359 .0690 0000 · Ol 0214 0327 0439 0552 0664 0777 0890 1002 1115 1227 1340 359 1144 1519 1585 1612 1623 1631 1638 1643 1648 1652 1655 1659 e No. 489 · 0000 Depth 3606 275 · 0000 266 .0164': 1040 .0090*~* 254 .0274 1435 1655 1700 .0384 .0202 (. 0290- .0314 · 0493 245 'C 246) 256 .0603 1714 .0426 272 .0712 1719 .0538 .0822 .0932 1721 1723 1725 · 1041 .ll51 1726 · 1260 .1370 .0650 10 REMARKS: *Fi rst interval '1727 1727 is equal 276 278 l0 Clock No. 10394 .0000 ~ 278 0313'*~* 1643 .0536 / 1703 .0760 · 0983 ,1206 · 1430 ,1653 .1877 .2100 .2323 .2547 ,2770 1711 1715 1718 1720 1722 1724 1725 1726' 1727 · 1727 2O 72 hour · 0000 .0623'_*,_i · 0990-B · 1069 .1514 .1640-E .1959 .1980-B .2405 · 2650-E · 2850 289 : 448 C 448) 501 626 SC 648) 417 SC 419 ) 596 ;C 6~5) 388 .0000 .OlOO .0211 .0322 .0433 .0543 .0654 ·0765 .0876 .0987 .1098 .1209 .1320 388 197 1568 1622 1642 1652 1660 1666 1671 1676 68O ! 6RR ! 687 4o 10 to ll minutes ** = 15 minutes *** = 8 minutes **** = 28 minutes *** = 56 minutes · . , . ~ - 9 minutes. PC = possible choke change BSC = beginning of surface closure ESC = end of surface closure_ SEE PAGE 2 FOR FOURTH, FIFTH, AND SIXTH FLOWS AND CLOSED IN PRESSURE;:PERIODS. Minutes~ SPECIAL PRESSURE DATA Gauge No. 753 J Depth 3580' '1 r~m~x Fourl h ~ Fourth xSx~e~R F iftt Flow Period Closed In Pressure Flow Period Time Deft. .000" PSIG Temp. Corr. Time Deft. .000" PSIG Temp. Corr. Time Defl. .000" PSIG Temp. Corr. Clock No. 10431 )~eg~kx Fifth Closed In Pressure PSIG Temp. Corr. l~Wx S i xtl Flow Period Ticket j hour No. 493656 (PaBe 2) xl~ Sixth Closed In Pressure Time Deft. .000" Time Defl. .000" 7.2 Time Deft. .000" PSIG Temp. Corr. .0000 365 .0000 200 .0000 288 .0000 381 .0000 298 .0000 .0180' 172 .0168 1456 .0201'* 146 .0337*~* 15.17 .0145'~'*'283 .0067 .0405 197 .0337 1535 .0425 154 .0562 1544 .0256 287 ..0134 .0505 .0787 .1012 .0673 ..0470-1 1561 1574 )SC 199 .0367 .0479 1557 275 279 1570 .0201 .0268 331 Loo - (.0530-F .0649 .0630 C 168) 298 .0855 401 .0842 1581 .0873 377 . 1236 1584 .0590 275 .0335 · 1080 426 . 1010 1589 . 1096 380 . 1461 1592 .0402 . 1140-]!SC' 429 .1178 1595 .1320 381 .1686 1598 ·0469 .1305 205 .1346 1601 .1911 1604 .0536 · 1530 200 .1515 1606 .2136 1610 .0603 · 1683 1610 .2360 1615 .0670 . 1851 1614 .2585 1619 .2020 1618 .2810 1623 PSIG TemD. Corr. 275 1286 1171 1407 1488 1521 1538 1547 1556 1561 1567 e No. 489 Depth 3606' Clock No. 10394 366 .0000 .0000 182 .0166 208 1504 345 .0202'* 238 204 .0332 1572 .0428 238 .0497 1592 · 0490- ~SC 207 336 .0663 1605 · 0829 .0995 .ll61 .1326 409 1614 1620 1628 433 1634 208 . 1492 1641 · 1150- :SC 437 212 Readin9 Interval 20 REMARKS: *Fi r., · 1658 · 1824 15 · 1990 1644 1648 1652 .0540-F .0654 .0879 · 1105 · 1330 t interval is equal C 246) 342 413 414 415 2O .0000 .0334'~* · 0556 .0778 .1001 .1223 · 1446 · 1668 · 1890 .2113 .2335 .2558 .2780 2O 415 1551 1576 1594 1608 1617 1627 1633 1638 1644 1649 1653 1656 7 _~ hour · 0000 .0140*~ ,0247 .0355 ,0463 ,0570 353 '*'353 339 337 310 300 10 .o000 .0066 ·0132 .0198 .0264 .0330 ,0396 ,0462 · 0528 ,0594 .O66O to 16 minutes. ** = 18 minutes. *** = 30 minutes. **** = 13 minutes, 300 1214 Ill2 1410 1513 1546 1562 1573 1581 1588 1593 Minutes -- BSC = beginning of surface closure ESC = end of surface closure PC = possible choke change '°"-'--"'-'"'--"'-""-" SPECIAL PRESSURE DATA 75¢ B/74 Drill Pipe or Tubing ................ Reversing Sub ................. ..... O.D. I.D. 11 Water Cushion Valve ................ Drill Pipe ........................ 4 1/2" Drill Collars ...................... 6 1/4tt Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. 5 Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... 5~t AP Running Case .................. 5~ Hydraulic Jar .................... 5~t VR Safety Joint ................. 5~ Pressure Equalizing Crossover ......... Packer Assembly ................... 8.20~ a'~~tx. P.e. rts ................. 2 7/8" Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ............ · Blanked-Off B.T. Running Case ....... 3 7/8't ~ I-~$00..Ten~p .... De.'.v. .... 5 7/8" Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ......... · Total Depth ....................... 2,75" 5,826" 2 7/16" .88" .75" .87" 3.00" 1.75" 1.00" 2.44" 2.44" .T.L~KET NO. 493656 LENGTH DEPTH , 3374' 188' 4,89' 8.47' 7.18' 4.05' 5.06' 3.52' 3379' 4.59' ', 8.80' 4.09' 1.06' 3580' 3592 ' 3606 ' 3609' 3609' ii Ticket F L U I D S A M P L E D A T A Date 8-8-75 Number 607830 · " -Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK HALL District ANCHORAGE ~o cc. on MR. GENTRY & ,. cc. Water Tester MR. PRUITT Witness HARMON cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY NM S ' Gravity ° APl @ °F. EQU I PM E N T & HOLE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation 98 ' Ft. CONTENT Net Productive Interval 3084' - 3094' Ft. Recovery Water @ °F. ppm All Depths Measured From Kelly Bushing - Z0' Recovery Mud ~ @ ~ °F. · ppm Total Depth 3735' Ft. Recovery Mud Filtrate ~@ ~°F. ppm Main Hole/Casing Size 95/8" - 47# Mud Pit Sample -- @ ~ °F. ppm Drill Collar Length 188 m, I.D. 2 7/16" Mud Pit Sample Filtrate~ @ ~°F. ppm Drill Pipe Length 28] 5' I.D. 2.441" Packer Depth(s) 3033 ' Ft. Mud Weight 10 vis cp Depth Tester Valve - ~)~{~' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion NONE Ft. Pres. Valve NONE Choke ¼"-3/4" Choke 3/4" , · Recovered Feet of No recovery reported [ · Recovered Feet of Recovered Feet of ~' Recovered Feet of ~ --I Recovered Feet of Remarks On 8-7-75 - opened tool - pumped in KCL water and diesel at 2230. Closed at the surface at 2253. Opened at 0110 - started swabbing at 0210 AH. Pulled tools loose and started out of the hole with fluid in the drill ,on pipe - did not reverse... CHARTS INDICATE POSSIBLE PARTIAL PLUGGING OF THE TOOLS.. , Gauge No. 489 Gauge No. 753 Gauge No. TEMPERATURE TIME Depth: 3021 ' Ft. Depth: 3045' Ft. Depth: Ft. ,i-'~ 72 HourCIock 72 HourCIock HourCIock Tool 8-7-75 ^.M. Est. °F. Blanked Off - Blanked Off YES Blanked Off Opened 2230 P.M. , 3048'( OpenedT ~ ,~p.M.s~T%7~'M' _Actual 75 °F. Pressures Pressures Pressures Bypass Field Office Field Office Field Office Reported' ' Co~'p~J~"~d- -Initial Hydrostatic - 1577 - 1587 Minutes Minutes - · -~ Flow Initial SEE SPE( IAL READING SHEET !'OR THE ~.= ~-~ Final REHAINDE]R OF THE READINGS. . -_ 20 Closed in _ 35 r-~o Initial Flow J u ~ Final J~l~ Closed in ~- Initial ~ Flow .~ ~ Final Closed in Final Hydrostatic - 1~577 - 1587 ,o ....... ,_,.., .... ,,,,, ..... FORMATION TEST DATA P-O P-1 P-2 P-3 P-4 P-5 P-6 P-7 P-8 P-9 PLIO P-Il P-12 P-13 P-14 P-15 P-16 P-17 P-18 P-O P-1 CITIES SERVICE OIL~MPANY Lease C~er/C6m~7 Nme B.T. 489 B.T. 753 B.T. ~07830 T±cket Number Depth 3021 ' Depth 3045' Depth . 72 Hour Clock 72 Hour Clock .~ ~sIG Time Def,. .~_ PSIG Time Dell. t-~-~ Time Dell. Log Temp. Log Temp. Log Temp. .000" Corr. .000" Corr. ,000" ~q Corr. MAXIMU~ INJEC11LIN MAXIMU~,I TNJF£T ON' , , 2793 ..... 2777~ , , FINAL INJECTION- FI, NAt iNJEcTI, Oli,- , , 1572 1578 · , , i, FLOW 'PERIOD - ,,.2.~iM~NUTE, ·FLOW ~EiRI.OD - ~0 MINU:F!iS.' " , ,, .000 , 1285. .000 , 1292.,~- ,,. , .020 llG1 .022 . , 1172 CLosED'' IN PR~SSJRE CLO§~E.6]],iN PRES~,URE ' , .... PERIOD O~ 35 MI~UTES. PERIODiOF35 Mi NUTES...~ .... · 000 ,000.' 1172 .OOll 1437' .OOll 1449':I ' ' '" ·0044 14~.5 ,,0033 , , ,' 14.5'6' . ,, . · . 0054 ...... 1450 .005,6 1460, . .0076 1455 ·0078 ..... 1464 . ., ., , .00',,9,8 l~b6 .0!00 ,. 1,467, · 0119 ,,. 145/ .0122 ...... .1470 .... ,. ~)141 1~60 i! ,..0145 .... '~ 1472 .0163 ' 1462 '! d'16..7 .01,85 ,, 1465 .0189 . ],4.76 , ,. .0206 ~466 0211 ,, 1478 · 0228 " 146/ , ~' 0'2,3.3', 1479 .... .0250 ' , , 1468 i! .0256 l'4'~'l ........ 0271 m~'b9 I 0278 1482 · , ...... ,· ,~ ,-,, ,, , i , i i . 0293 14! i . 0300 1483 "' ' '" I i ........ i · 0315 14 / I i . 0322 1483 .0339 Io./z i) 0'345 14~'4 ..... '' !I .......... .0358 )¢/3" ,~ .0369 1484 0380 ' . ~4/j I: '.0390 ...... 1484 " ~ 'iNiERVAL' '~ FiiNu~.Ii"."'iNTE~VAL '~ MINUTE ...... "' 2 FtlNU)~ i~iiERFALS".,,'" 2 MINUIIE INTER'I'ALS , ,,, , i i , i i SECOND PLOW PkI(LUU - I,SECOr~D ~LO'~i P'~'R] OD - ' .... 512.! MINU'I'~S. i) 512.1 ~INUTES. ' .000 l-i4y I .000 11'97 ' '' ! I ' '"" · 5/3 )J~b !, 5'69 1364 , , ,, ,, , , , ,, ,, i · ~;i....... , ,, , ,, · ~ , ,__ L__ , SPECIAL PRESSURE DATA Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe .............. ~ ...... Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual ClP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case ................... Hydraulic Jar .................... VR Safety Joint ................... Pressure Equalizing Crossover ......... Packer Assembly ................... zm~~x. Perfs ................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... :x~tx~~'T-. 5 0.0..Tem:p ......... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... aa P. Z 7/8" 6.2S" 2 7/8" 3 7/8" 3 7/8" I, Do 2,75" 2,441" 2 7/16" ,88" .7S" .87" 3,00" 1,75" 1.00" 2.44" 2.44" TICKET NO. 607830 LENGTH DEPTH 1.00' 281S' ~88' 4.89' 8.47' 7.18' 4.05' .3019' .3020' 5,06' 3.52' 4.59' 8.80' 4.09' 1.06' 3021' 3033' 3045' 3048' ~3735 ' rOR~ I$7,RI--PRINT£D IN U.$.A. FC~I !! PMP'NT r~ATA LITTLE'S 9ee76 F,~rm No. P-...4 lq.L~. ~' 1-70 STATE OF . .~SKA OIL AND GAS CONSERVATION CON~II'I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DL~PLICAT~: AP1 NUMERICAL CODE 50-283 -20047 LEASE DESIGNATION AND SEIRIAL ADL 58801 T IF INDIA]ff. AL~TT'EE O]~ TRIBE £ I 4ENG 2. NAME OF OPERATOR Cities Service 0il Company 3. ADDRESS OF OPEP~TOI~ 1016 West 6th Avenue, Suite 420~ Anchorage, AK 99501 4. LOCATION OF WEL~ t~ I I 5 ENG L,~IT FARM OR LEASE NAME /[ t GEGL ~__ Lewis River I--T-~-'~E~[ ~ t I I ,,, wttacat k l 1600' GWL, 1700' FNL X = 351,875 Y + 2,681,050 Sec. 2-T14N-R9W~ SM 12. PERMIT bra 75-5 13.REPORT TOTAL DEPTH AT END OF MONTH. CHAJ~GES IN HOLE SIZE. CASING AND CKMENTiNG JOBS INCLL'DING DEPTH SET AND VOLUMES USE~. PEI~FOKATIONS. TESTS ~ ~.SUL~ F~HING JO~ JUnK ~ HO~ AND SIDE-~CK~ HO~ ~D ~Y O~ SIGNIFIC~ ~G~ ~ HO~ ~ITIONS 9/1/75 119 days. TIG~ H0~ PBTD: 5900 ' Present Operations: Attempting to 'set plug tn long string Remarks: Working wireline 'to free plug stuck in sliding sleeve mandrel ~ 5071' 3 hrs. we wireline cutter and oil jars 4 hrs. Working on lubricator, pack off would not close, bled fr~ 235~ to 350~[, SI. Pressure built to 1800#, jars on wireline plug 'started to work 1 hr. Jar and sheer pin, POOH, found running tool coated with fo~atton sand .2-1/2 hrs. .we replac~ent lubricator' and packing 3 hrs. Replace lub- ricator 1 'hr... WIH With fishing tool and jar plug loose, POOH 6 hrs. FI~ well to clean sand on 1/2" choke 2-1/2 hrs. PU plug and start in hole 1 hr. 9/2/75 120 days TIG~ HO~ . PBTD: 5900 ' Present Operations: GIH with X-lock mandrel to. plug bott~ z~e. R~arks: GIH with X-lock mandrel set ~ 5071' 2 hrs. GIH and fish X- lock mandrel 1-3/4 hrs. GIH to open lsiding sleeve ~ 5071' 2 hrs. ~11 back pressure valve fr~ short string '1/2 hr. Flow l~g string, rec mist water and sand, no diesel which ~ndtcated sliding sleeve ~ 5071' wasn't open. Gas rate 3310 Mc'fpd, 3/4" choke, 600# FTP, choke ' plugged, 3 ball sealers, cut choke out, SI. L~g string, open short. string 50~t, fl~ 2 bbls and died, 5-3/~ hrs. Swab short string, 10 bbls, well kicked off 1 hr. FI~ to clean on 3/4" choke, rec water and diesel, rum th~ separator, s~low 3900..Mcfpd., 6i0~ FTP, 3/4" choke 5 hrs. Change over to long string' and fl~ to c%ean 1 hr. OCT 1975 CONFIDENTIAL , ^ DIVI$10 OF OIL smm~ ~~ ~b~~ =~ Drilling Engineer NOTE--RIIQII on this fo~ il required for to~ calendar ~nthT rlgOrdltll Of lhl ItOtUl of oPlrationl~ and must ~ flied i. d.pli~tl with the oil and gas conlervatbn commiffee by the 15~ of the suec~ding ~n~, ~le. otherwise directed, Page 2 9/3/75' 121 days TIGHT HOLE PBTD: 5900 ' DC: $15,257 CC: $3,424,564 Present Operations: Flowing long string, will set back pressure valves~ in tubing and.start rigging down ~ 6:00 AM. Remarks: GIH with wireline and X-lock mandrel set ~ 5091' 3-1/2 hrs. Bled tubing pressure from 2300 Psi to 400 Psi 1/4 hr. GIH and open sliding sleeves 1-1/2-hrs. Close top sliding sleeve 1-1'/4 hrs. Flow- ing long string, no diesel to surface, flow pressure indicate bottom plug leaking 1 hr. SI to check pressure; 2300~ TP. 1 hr. GIH and re- set plug 1-1/2 hrs.. Check flow, rate the same 1/2 hr. SITP 2300# 1/2' hr. GIH and pull X-lock mandrel 2 'hrs. Flow string to clean tubing,' choke plugged with ball sealers 2 hrs. GIH to 5551' with X-lock man- drel, 'could not set, POOH 2-1/2 hrs. 'GIH to'5091' with X-lock mandrel,' could not ~et, POOH 2 hrs. GIH with shifting tool,' tools indicate sliding sleeve @ 5071' is open 2' hrs. GIH to close top 'sliding sleeveI .4421 1-3/4 hrs. Flowing long string 24/64" choke, will start rigging down @ 6:00 AM Alaska time' 3/4 hr. 9/4/75 - Well Shut in, moving out rig. 9~20~75 9/21/75 9/22/75 Shut 'in to rig up test equipment. Opened long string and bottom perforations. Flowed 6 hrs on 30/64" choke, FTP 1420 Psi, 2738 Mcfpd. SI 6 hrs and 20 rain, SITP 2365 Psi. 9/23/75 - Flowed bottom zone for~ 24 hfs on 23/64" choke, FTP 1320 Psi, average of 3054 9/24/75 Mcfpd. 9/25/75 Flow tested bottom zone on 22/64"'choke, FTP 925 Psi, 3242 Mcfpd. 9/26/75 Shut in on bottom zone for pressure buildup. 1 rain 1275~ 5 rain 1530~ 10 min 1760~ 30 min 2025~ 90 rain 2170~ 120 rain 2230~ 240 rain 2300~ 450 min 2292~ 9/27/75 9/28/75 Closed sleeves on long string, opened short string for 24 hrs on 21/64" choke, FTP 1060-1090 Psi, 3423 Mcfpd. Shut in @ 4:-00 PM for top hole buildup. 0 rain 1060~ 1 rain 1235~ 5 rain 1450~ 10 min 1570~ 30 min 1740~ 90 rain 1760~ ! min 1764~ CONFIDENTI L · rain 1806~'~ OCT ,S 1975 Page 3 9/29/75 9/30/75 Continued with shut in of short string. 765 rain 1819# 1350 rain 1825~ 1530 min 1830# Opened long string to clean up. Flowed on 21/64" choke, FTP 1120~, 3351 Mc fpd. Continued with shut in of short string and flowing of long string, 21/64" choke, 3350 Mc fpd. TITLE: Drilling Engineer DATE: 9/30/75 CONFIDENI'IAL OCT 197§ 10 X I0 TO THE INCH elo x 15 INCHES KEUFF'EL & ESSER CO. ~4AoI~ IN U.S.A. 47 0703 :. CONFIDEN]IAL · u!~nqs ~u!aq ~a~e pauodo s! IIa~ oq~ am~ qaeo ~OlT~ oq~ ~q~!I-pu~'~aou~nq ao~aq aq2 2q§!i,oA se~ 2ua!o!~ns ap!~oad oA XImOIS IIan aq2 uado oA Ka~ssaoou aq II!~ ~I '~uamd!nbo ~!a aqA Kq pap!Aoad meaAs q~im paAe~ado Xisnoi~aad sem sTqa aouTs aoaeoq ~uTI ~qa ~o~ ion~ apiAo~d oA aa~a~ aoi~i~o aq~ ~o meo~asu~op ~uii aoi~ ~q2 moa~ ~pwm ~q IIIm uoI2oouuoo s~ V 'IIOn oq3 o3 p~3o~uuoooa · pues pooupoad oqA qAia smoiqoad p!oAe o~ pou~!sop s! ~anpoooad ~s~ ~u~I -p~onpoad ~uioq s!'pues s~ ~uoI os ~uImoI~ s!'II~m ~q~ ~I!qa ~u!qnA ~qA u! sIOO~ ou!I~a!m ~u!uuna p!oAe osIe pInoqs ~M '~! ~u!~°I~s pu~ ~nId ~u!qn~ ~q~ uo ~uiI~s pues ~o paezeq ~q~ ~o osneooq ~u!~s~ ao.~ ~uoz a~moI ~q~ moa~ ~uoz ~Ipp!m ~q~ ~IOS! o~. 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SlUT esn lou oo) S'1'13M NO SIt:lOd3T:l ONV S30110N A~IONnS 331/IVdY400 NOIlVAI~3SNOO 9¥9 (]NV '110 V~SV'IV ~0 31VIS ele:)lldnO Ul ,,sUodetd ].uenbesqns,, '~ %~,/ e~e:)lldlJL ul .~suop, ue),u I, ),ltuqns t~Ot~-O t State ¢,,Alaska DATE: ~y 28, 1975 FILE -'NO: TELEPH°NE NO: SUBJECT: ~E .Test :e~ Ci ties Service_ Lewis_River No,1, Onshore "-.May,,!:4"__ ~75.- Randy Hicks, Ctl~ies,Sentce 0ti1 _Company. (CSO)-dr1'llino engt~: :aler~ me early May 13, 197.5, ~t.:-testtng...~:-' t. ~s 'imminent.- · :~ted approval- to t~t BOP.'s at. 25~ ps!g!:,~.:~.cOUld use-. t _be~,r ' - ~proval was not granted. Durtr~ the prevtous_.'.~y.a~:, night 13-3/8' :i, ?/'ceme_._..nted short of its objective due ite-~le ~.' ~'BOP equ~:.pment ?,:?,-'.lotiOn was started, At 8:45,AN, Ra~ called-:~t.--~ was-~ady to test-. :...~ur: :departure would be at 10:00. AM Via'CS0 : ~lgbt, I left-the .D : 'of 0tl and Gas office at g:o0 AN and d~e. to: Air. ~I ce -at :' ':i .' 'l~y' l~loore~ Brinl<eri~ff relle~-tool p~~.i~ / , 'C$0 d~!'1.t l~g · Ll-g, hti:eg Corporation. I 1.eft 'm ~ ..... ~ a .10:~0 Alii, He flew down the .i.~:t~. o.f. Cook ?~.-1-~d t~-$:f Field airstrip, Eleven. (111 ~tlves met our plane. Bob Chad,;tek, outgoi~-:.:~:dH3l, tng .foreman- told had held 2500 pstg pressure-on the bl'i-d :r.-~il ~ ~..pmnps.. ! told ;that wasn't enough.. He was aware of ~t ar~:'i~:d~,t~ ;plaened to use. Haili cementing pumps for testing ............. .-... - ............ - '. 'The plane.and vehtc-les 'i-eft :the a!.~tr.~t'p. . .:~.~ Snidley,. tl~ · .-geologist, Geurley, Strobel., HiCkS amt -I-drove ~':;.i3:_: al:gravel .~.'~ia:?: '-' ' Yehtcle. The first part of the read'.beioegS:~_. '-0tl Of- ' · ..a~d CSO pay~$ocal a Use fee-+:. The last part t!s::l:~: ci'tle$ 0!1 -: ~ were several partial washeu~ ..~.'to ~:'!~'.: ~. e~..--.' . ... .... st111 passab!e and major road.repairs Wti'! be ~. b~k-up-- We arrtved at the CSO - Lewis. River camp a.~".~at' :~~ .After a s~.hort stop on, about a 'mile, to the CSO Lewis .R!..~: No,::...). ~Illlng I~ ~oc.'atten. See The crew had set the test plug tn the ~rillt~.'.s~l~' .clOsed the bii~nd rams":.~'.._ p~sured up wtth the iud pumps .to ~5~ .pslg!: -::-.~ .blt~ rat ~.the iiae valve next. to the stack, ..... Largip~.l(ners. we~..:i ~ ~!.'mud .p~ to ia~ .circulating veiume required for the-t~.-pa~ef.: the'i:~:t'e~ This ii ava{.lable pump p.ressere .~ abOUt ZS.~....-pstg. Rand~ Ht~.~.. ~a!n req_uested accept a 2-500:pstg'test press..~.-so ~-:..~/.~ ~Scou~.~ i~ed.... I_refused;~..~e_ ' crew was stt11 wa1'dtag .:~.e oho :ko: ~:?.eld .~ to. have '.be,rs of work, ,so we returned. ~..~. far 1...~h~ ..-Rfte~ R._~y .to get the ~11tb~-crew free Se~l--.]~an' Rtve~-' ~.i.t-:No, 14-31 drili run their feinting pump for ear BOP ~l-,t* , - -pa,alq:m sea ~sa~ §-~sd 000£ poo~ · puc da~ea q~l~ POLLU se/A dared OtLL -dmnd ~qpur4s a~atl:~ o3;e~ ~t:)gq ~l~qeaL sea-a, mssaad ~m4~ p~z~ms ~CLLeU~ uo0,anq~LLeH 'peamL[O~ $)ieaL.aO~. qo~s anoq Z/L-~ Y '~,to.Su~paeLq p~ae'4.s uaqo, salnu~m g ao=~ pLaq a. mssaad ~Leeds 6u~LU, ap-aq~ ut ~as 5n~a · q~a pLe.~uma a;oqo puc aU~L ~0 'sama pu~.tq 'a~n u~ ~.sd '~; ~nd. uo~tLL-~ ~ O;:s ~¥ -aa~e. oL~s. aump ao,~ ~LL~ smq-Ltaa V *ao.~ p&nb-tt ao~ pazt. tt~n st~ ~tueI o~.Idas pue LOOdssao y '~-~ m~_~o puc tm u~t~ ~,taA SWa tmae aql '~tua~s a~,t'n'o se~ ~a~, 6u~~s- ~ ~ ~'!tq-~ea s~ uot'~t dmeo '~'tttq puc papoo~ ,(L~-s~ Bate ~ -~ .~-e~ta~ e ~1oo~ !ttnt ~ .6ut,mit gZ6 L ' 87, ;Ced -g- dta,L pLa~:l-.tatt~ -.tp 'tt~'aaqt~5 '~ '0 'Xaoloe~sLo, es aaaa sm~ aaq~o LLV aOOL~ LeUOl. O,~ppe me pu~ '6u~lsa'4ea puc a~edaa paa~nbaa-' aLCTe~snl~pe LenUmU. (g) ORL 'L'Lam L 'ON. ~~ uo SUOl.~,eaado 6U~LL~ap puc ~~nb~ a~UaAaad~'"~Lq ano aam4a d~a3sa~e gGnLa8 aq~ o~ ~La~m pu~ ~eda~ ~ · aRoap ~a~p~ m,~:~ 'Nd ~:OL o,e a~,aLdmoo s-e~ 3~ atU. · sa'4oqo aLqeo, snJ?pe Lenuem oaq aq~ ut~ ~ed. L-eUaa~u~ ~ L L~SU~ pug upr~qo o~ 6L6 L '8Z ~Celd -~- L 'ON d~aj. pLa~i-aaLLU~r . ':: 177 OperatiOns Off "pad,i- ~, 18. "General .H0uSekeePtns','- :' ''~ .::'i' :'.19.-' Abd. Marker in place :: : .. : Water Well cOVered .. · ,~... ,.: ~!;:~: ..:~ , ., i ~ . . '..-.': ', .. 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